Entergy Louisiana, LLC COLLATERAL TR MT (ELC) 10-Q 5 Nov 19 2019 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2019	Oct. 31, 2019
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	Sep. 30, 2019
Amendment Flag	false
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q3
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, Country	US
Entity Address, Postal Zip Code	70113
Entity Common Stock, Shares Outstanding		199,102,083
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, Country	US
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, Country	US
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, Country	US
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, Country	US
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, Country	US
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, Country	US
Entity Address, Postal Zip Code	39213
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Five Point Six Two Five Percent Series First Mortgage Bonds Due June Two Thousand Sixty Four [Member] | Entergy Texas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	EZT
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 5.625% Series due June 2064
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
Mortgage Bonds Four Point Seven Percent Series Due June Two Thousand Sixty Three [Member] | Entergy Louisiana [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ELU
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.70% Series due June 2063
Mortgage Bonds Five Point Two Five Percent Series Due July Two Thousand Fifty Two [Member] | Entergy Louisiana [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ELJ
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 5.25% Series due July 2052
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
Mortgage Bonds Four Point Seven Five Percent Series Due June Two Thousand Sixty Three [Member] [Member] | Entergy Arkansas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	EAE
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.75% Series due June 2063
Mortgage Bonds Four Point Nine Percent Series Due Decembertwenty Fifty Two [Member] | Entergy Arkansas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	EAB
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.90% Series due December 2052
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		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 3,140,575	$ 3,104,319	$ 8,416,367	$ 8,496,970
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	596,939	729,269	1,542,592	1,638,367
Nuclear refueling outage expenses	52,044	37,937	153,447	116,057
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	805,696	854,013	2,430,617	2,477,699
Asset Impairment Charges	198,086	155,215	288,483	297,082
Decommissioning	101,811	93,829	308,557	285,834
Taxes, Other	165,731	161,916	487,715	485,682
Other Depreciation and Amortization	379,219	324,628	1,099,990	1,022,099
Other regulatory charges (credits) - net	4,781	37,097	(38,698)	223,416
Costs and Expenses	2,620,646	2,833,284	7,274,410	7,798,673
OPERATING INCOME	519,929	271,035	1,141,957	698,297
OTHER INCOME
Allowance for equity funds used during construction	33,161	32,354	108,546	92,367
Investment Income, Net	82,295	177,081	406,663	265,086
Miscellaneous - net	(50,086)	(43,591)	(160,614)	(123,439)
TOTAL	65,370	165,844	354,595	234,014
INTEREST EXPENSE
Interest expense	201,412	195,311	603,517	570,548
Allowance for borrowed funds used during construction	(14,773)	(15,244)	(49,034)	(43,177)
TOTAL	186,639	180,067	554,483	527,371
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	398,660	256,812	942,069	404,940
Income taxes	29,201	(283,006)	73,430	(519,937)
Consolidated net income	369,459	539,818	868,639	924,877
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	$ 4,219	$ 3,439	$ 12,438	$ 10,317
Earnings per average common share:
Basic (in dollars per share)	$ 1.84	$ 2.96	$ 4.42	$ 5.06
Diluted (in dollars per share)	$ 1.82	$ 2.92	$ 4.38	$ 5.01
Basic average number of common shares outstanding (in shares)	198,932,387	181,002,303	193,876,557	180,845,440
Diluted average number of common shares outstanding (in shares)	200,492,935	183,664,583	195,685,851	182,692,325
Net Income (Loss) Available to Common Stockholders, Basic	$ 365,240	$ 536,379	$ 856,201	$ 914,560
Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	2,812,934	2,697,887	7,279,683	7,276,374
Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	27,269	26,352	112,916	112,990
Competitive Businesses [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	300,372	380,080	1,023,768	1,107,606
Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	316,339	439,380	1,001,707	1,252,437
Entergy Mississippi [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	398,732	367,734	983,713	1,037,166
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	87,386	78,533	188,006	207,724
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	69,253	69,936	195,357	193,979
Taxes, Other	26,673	26,024	78,613	75,212
Other Depreciation and Amortization	44,339	37,752	123,145	114,293
Other regulatory charges (credits) - net	5,771	5,487	11,708	133,715
Costs and Expenses	311,708	322,519	820,290	1,014,320
OPERATING INCOME	87,024	45,215	163,423	22,846
OTHER INCOME
Allowance for equity funds used during construction	2,079	2,251	6,341	6,351
Investment Income, Net	462	1	1,011	26
Miscellaneous - net	(1,648)	116	(2,238)	(1,866)
TOTAL	893	2,368	5,114	4,511
INTEREST EXPENSE
Interest expense	15,922	13,950	45,804	41,916
Allowance for borrowed funds used during construction	(892)	(944)	(2,683)	(2,662)
TOTAL	15,030	13,006	43,121	39,254
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	72,887	34,577	125,416	(11,897)
Income taxes	16,650	(16,156)	27,114	(123,715)
Consolidated net income	56,237	50,733	98,302	111,818
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	0	238	0	715
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	56,237	50,495	98,302	111,103
Entergy Mississippi [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	398,732	367,734	983,713	1,037,166
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	78,286	104,787	223,461	289,397
Entergy Arkansas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	687,526	568,399	1,776,267	1,614,028
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	109,779	164,438	370,534	379,240
Nuclear refueling outage expenses	17,381	19,062	51,823	61,623
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	188,299	188,882	542,765	536,032
Decommissioning	17,422	15,226	50,351	44,971
Taxes, Other	31,783	27,972	87,327	80,322
Other Depreciation and Amortization	78,594	73,579	231,502	218,261
Other regulatory charges (credits) - net	1,018	(13,758)	(8,873)	(29,378)
Costs and Expenses	505,350	533,614	1,481,846	1,486,095
OPERATING INCOME	182,176	34,785	294,421	127,933
OTHER INCOME
Allowance for equity funds used during construction	3,977	3,735	10,777	12,214
Investment Income, Net	8,788	12,060	19,193	21,352
Miscellaneous - net	(4,286)	(3,063)	(12,704)	(10,815)
TOTAL	8,479	12,732	17,266	22,751
INTEREST EXPENSE
Interest expense	35,454	31,632	104,664	92,315
Allowance for borrowed funds used during construction	(1,641)	(1,739)	(4,384)	(5,737)
TOTAL	33,813	29,893	100,280	86,578
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	156,842	17,624	211,407	64,106
Income taxes	7,126	(111,266)	(27,729)	(183,595)
Consolidated net income	149,716	128,890	239,136	247,701
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	0	357	0	1,071
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	149,716	128,533	239,136	246,630
Entergy Arkansas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	687,526	568,399	1,776,267	1,614,028
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	61,074	58,213	156,417	195,024
Entergy Louisiana [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,231,677	1,206,612	3,297,324	3,308,744
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	259,419	318,987	627,240	700,296
Nuclear refueling outage expenses	14,026	12,969	40,225	38,739
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	249,773	239,230	726,496	724,604
Decommissioning	15,606	13,654	43,544	39,906
Taxes, Other	49,602	44,594	145,942	143,021
Other Depreciation and Amortization	137,891	124,030	394,271	366,950
Other regulatory charges (credits) - net	(29,224)	(1,433)	(90,762)	30,781
Costs and Expenses	894,923	970,094	2,565,106	2,780,746
OPERATING INCOME	336,754	236,518	732,218	527,998
OTHER INCOME
Allowance for equity funds used during construction	14,609	20,423	59,194	57,292
Investment Income, Net	45,237	53,009	166,721	143,137
Miscellaneous - net	(15,067)	(25,782)	(79,717)	(56,217)
TOTAL	44,779	47,650	146,198	144,212
INTEREST EXPENSE
Interest expense	78,350	73,084	230,684	216,762
Allowance for borrowed funds used during construction	(7,041)	(10,168)	(28,145)	(28,382)
TOTAL	71,309	62,916	202,539	188,380
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	310,224	221,252	675,877	483,830
Income taxes	54,964	2,944	109,900	(30,430)
Consolidated net income	255,260	218,308	565,977	514,260
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	255,260	218,308	565,977	514,260
Entergy Louisiana [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,221,874	1,196,278	3,252,826	3,263,073
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	9,803	10,334	44,498	45,671
Entergy Louisiana [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	197,830	218,063	678,150	736,449
Entergy New Orleans [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	194,204	200,182	533,191	566,903
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	27,013	54,754	84,963	93,859
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	32,755	30,593	95,305	87,312
Taxes, Other	15,142	15,551	41,819	43,534
Other Depreciation and Amortization	14,756	14,059	43,146	41,756
Other regulatory charges (credits) - net	7,571	5,853	9,716	18,313
Costs and Expenses	165,328	178,638	470,670	499,547
OPERATING INCOME	28,876	21,544	62,521	67,356
OTHER INCOME
Allowance for equity funds used during construction	2,793	1,694	7,769	3,762
Investment Income, Net	109	30	352	330
Miscellaneous - net	(1,019)	(660)	(3,467)	(2,401)
TOTAL	1,883	1,064	4,654	1,691
INTEREST EXPENSE
Interest expense	6,046	5,388	18,001	15,936
Allowance for borrowed funds used during construction	(1,115)	(626)	(3,102)	(1,390)
TOTAL	4,931	4,762	14,899	14,546
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	25,828	17,846	52,276	54,501
Income taxes	920	(3,561)	5,342	3,943
Consolidated net income	24,908	21,407	46,934	50,558
Entergy New Orleans [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	176,738	184,164	464,773	499,584
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	17,466	16,018	68,418	67,319
Entergy New Orleans [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	68,091	57,828	195,721	214,773
Entergy Texas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	442,877	477,231	1,146,931	1,229,657
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	64,211	79,130	129,285	154,925
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	69,937	58,795	190,989	171,317
Taxes, Other	20,870	20,752	60,773	61,461
Other Depreciation and Amortization	38,722	31,365	113,071	93,272
Other regulatory charges (credits) - net	27,662	33,550	66,574	85,064
Costs and Expenses	373,367	377,265	1,024,658	1,029,972
OPERATING INCOME	69,510	99,966	122,273	199,685
OTHER INCOME
Allowance for equity funds used during construction	7,454	2,222	18,948	5,716
Investment Income, Net	486	601	2,542	1,698
Miscellaneous - net	115	468	980	(154)
TOTAL	8,055	3,291	22,470	7,260
INTEREST EXPENSE
Interest expense	21,379	21,760	63,992	65,646
Allowance for borrowed funds used during construction	(3,534)	(1,253)	(9,370)	(3,224)
TOTAL	17,845	20,507	54,622	62,422
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	59,720	82,750	90,121	144,523
Income taxes	(13,504)	16,904	(43,381)	30,538
Consolidated net income	73,224	65,846	133,502	113,985
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	110	0	110	0
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	73,114	65,846	133,392	113,985
Entergy Texas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	442,877	477,231	1,146,931	1,229,657
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	151,965	153,673	463,966	463,933
System Energy [Member]
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	23,748	14,484	66,335	44,939
Nuclear refueling outage expenses	8,412	5,906	25,013	12,698
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	49,533	48,969	147,283	143,003
Decommissioning	8,976	8,626	26,663	25,624
Taxes, Other	7,120	7,106	21,835	21,069
Other Depreciation and Amortization	26,613	4,355	79,761	71,143
Other regulatory charges (credits) - net	(8,016)	7,398	(27,059)	(15,080)
Costs and Expenses	116,386	96,844	339,831	303,396
OPERATING INCOME	29,086	(17,879)	84,754	36,468
OTHER INCOME
Allowance for equity funds used during construction	2,251	2,028	5,518	7,032
Investment Income, Net	8,215	23,738	21,577	33,567
Miscellaneous - net	(1,300)	(1,421)	(4,018)	(4,391)
TOTAL	9,166	24,345	23,077	36,208
INTEREST EXPENSE
Interest expense	8,546	9,753	26,467	28,734
Allowance for borrowed funds used during construction	(551)	(515)	(1,350)	(1,783)
TOTAL	7,995	9,238	25,117	26,951
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	30,257	(2,772)	82,714	45,725
Income taxes	5,226	(25,744)	9,633	(22,942)
Consolidated net income	25,031	22,972	73,081	68,667
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	25,031	22,972	73,081	68,667
System Energy [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 145,472	$ 78,965	$ 424,585	$ 339,864

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Proceeds from Sale of Productive Assets	$ 19,801	$ 12,915
OPERATING ACTIVITIES
Consolidated net income	868,639	924,877
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	1,634,677	1,517,344
Deferred income taxes, investment tax credits, and non-current taxes accrued	373,723	82,641
Impairment of Long-Lived Assets Held-for-use	225,175	210,263
Changes in working capital:
Receivables	(231,005)	(153,703)
Fuel inventory	(14,399)	49,728
Accounts payable	(175,246)	79,949
Taxes accrued	(2,420)	43,510
Interest accrued	(2,314)	(9,398)
Deferred fuel costs	90,319	(25,284)
Other working capital accounts	(19,232)	(86,063)
Changes in provisions for estimated losses	14,114	28,599
Changes in other regulatory assets	(92,861)	207,135
Increase (Decrease) in Regulatory Liabilities	(19,115)	(413,684)
Changes in pensions and other postretirement liabilities	(132,044)	(345,526)
Other Noncash Income (Expense)	(400,064)	(250,884)
Net cash flow provided by operating activities	2,117,947	1,859,504
INVESTING ACTIVITIES
Construction/capital expenditures	(3,079,726)	(2,883,047)
Allowance for equity funds used during construction	108,867	92,829
Nuclear fuel purchases	(55,176)	(170,819)
Payments for Nuclear Fuel	(55,176)	(170,819)
Payments to storm reserve escrow account	(6,184)	(4,515)
Decrease (increase) in other investments	30,370	(36,140)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	2,369	0
Proceeds from nuclear decommissioning trust fund sales	3,518,616	4,177,919
Investment in nuclear decommissioning trust funds	(3,566,690)	(4,187,161)
Proceeds from insurance	7,040	10,523
Changes in securitization account	(4,213)	(12,985)
Net cash flow used in investing activities	(3,024,926)	(3,000,481)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	7,133,571	5,604,131
Proceeds from Issuance of Preferred Stock and Preference Stock	33,486	0
Common stock and treasury stock	89,303	24,646
Proceeds from Issuance of Common Stock	607,650	0
Retirement of long-term debt	(5,859,714)	(4,181,820)
Changes in credit borrowings and commercial paper - net	(24,550)	368,370
Payments for Repurchase of Preferred Stock and Preference Stock	50,000	0
Dividends paid:
Common stock	(526,408)	(482,865)
Preferred stock	(12,328)	(10,317)
Other	(9,175)	25,540
Net cash flow provided by financing activities	1,381,835	1,347,685
Net increase in cash and cash equivalents	474,856	206,708
Cash and cash equivalents at beginning of period	480,975	781,273
Cash and cash equivalents at end of period	955,831	987,981
Cash paid / (received) during the period for:
Interest - net of amount capitalized	584,622	558,381
Income taxes	(8,649)	18,200
Entergy Arkansas [Member]
OPERATING ACTIVITIES
Consolidated net income	239,136	247,701
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	351,390	335,939
Deferred income taxes, investment tax credits, and non-current taxes accrued	85,246	28,463
Changes in working capital:
Receivables	(70,395)	(33,422)
Fuel inventory	(5,350)	7,523
Accounts payable	(24,766)	(20,904)
Taxes accrued	(18,608)	30,686
Interest accrued	20,206	13,558
Deferred fuel costs	52,468	24,463
Other working capital accounts	44,803	(8,827)
Changes in provisions for estimated losses	8,841	10,013
Changes in other regulatory assets	(55,749)	22,574
Increase (Decrease) in Regulatory Liabilities	32,537	(218,518)
Changes in pensions and other postretirement liabilities	(26,136)	(64,461)
Other Noncash Income (Expense)	(57,011)	(12,203)
Net cash flow provided by operating activities	576,612	362,585
INVESTING ACTIVITIES
Construction/capital expenditures	(488,487)	(517,882)
Allowance for equity funds used during construction	11,016	12,572
Change in money pool receivable - net	(6,896)	(13,421)
Nuclear fuel purchases	(26,732)	(79,142)
Payments for Nuclear Fuel	(26,732)	(79,142)
Proceeds from sale of nuclear fuel	22,834	31,897
Change in other investments	(1)	1
Proceeds from nuclear decommissioning trust fund sales	199,031	259,331
Investment in nuclear decommissioning trust funds	(214,205)	(269,913)
Proceeds from insurance	0	7,043
Changes in securitization account	(3,238)	(4,821)
Net cash flow used in investing activities	(506,676)	(574,337)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	781,510	658,427
Retirement of long-term debt	(473,827)	(372,447)
Change in money pool payable - net	(182,738)	(166,137)
Changes in credit borrowings and commercial paper - net	0	(49,974)
Dividends paid:
Common stock	(115,000)	0
Preferred stock	0	(1,071)
Other	(2,931)	8,520
Net cash flow provided by financing activities	7,014	427,318
Net increase in cash and cash equivalents	76,950	215,566
Cash and cash equivalents at beginning of period	119	6,216
Cash and cash equivalents at end of period	77,069	221,782
Cash paid / (received) during the period for:
Interest - net of amount capitalized	80,644	74,966
Proceeds from Contributions from Parent	0	350,000
Entergy Louisiana [Member]
OPERATING ACTIVITIES
Consolidated net income	565,977	514,260
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	498,397	490,638
Deferred income taxes, investment tax credits, and non-current taxes accrued	174,825	167,603
Changes in working capital:
Receivables	(72,018)	(61,281)
Fuel inventory	(1,752)	6,120
Accounts payable	(40,131)	(20,481)
Taxes accrued	78,910	(22,893)
Interest accrued	5,102	2,382
Deferred fuel costs	(11,459)	(25,781)
Other working capital accounts	(62,332)	(5,086)
Changes in provisions for estimated losses	9,748	7,800
Changes in other regulatory assets	(103,635)	49,245
Increase (Decrease) in Regulatory Liabilities	(26,115)	(29,943)
Changes in pensions and other postretirement liabilities	(15,761)	(59,305)
Other Noncash Income (Expense)	(37,313)	(69,978)
Net cash flow provided by operating activities	962,443	943,300
INVESTING ACTIVITIES
Construction/capital expenditures	(1,277,108)	(1,322,633)
Allowance for equity funds used during construction	59,194	57,292
Change in money pool receivable - net	35,485	(2,444)
Nuclear fuel purchases	(63,157)	(32,362)
Payments for Nuclear Fuel	(63,157)	(32,362)
Proceeds from sale of nuclear fuel	11,608	54,088
Payments to storm reserve escrow account	(5,013)	(3,297)
Proceeds from nuclear decommissioning trust fund sales	307,164	943,306
Investment in nuclear decommissioning trust funds	(331,138)	(973,218)
Proceeds from insurance	7,040	3,480
Changes in securitization account	(6,467)	(8,056)
Payment For Proceed From Other Investing Activities	2,369	0
Net cash flow used in investing activities	(1,260,023)	(1,283,844)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	2,332,003	1,950,482
Retirement of long-term debt	(1,798,014)	(1,338,227)
Changes in credit borrowings and commercial paper - net	0	(43,540)
Dividends paid:
Common stock	(155,000)	(56,000)
Other	3,272	5,507
Net cash flow provided by financing activities	382,261	518,222
Net increase in cash and cash equivalents	84,681	177,678
Cash and cash equivalents at beginning of period	43,364	35,907
Cash and cash equivalents at end of period	128,045	213,585
Cash paid / (received) during the period for:
Interest - net of amount capitalized	219,323	208,028
Income taxes	0	(2,973)
Entergy Mississippi [Member]
OPERATING ACTIVITIES
Consolidated net income	98,302	111,818
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	123,145	114,293
Deferred income taxes, investment tax credits, and non-current taxes accrued	32,596	40,537
Changes in working capital:
Receivables	(37,843)	(49,456)
Fuel inventory	(3,872)	33,705
Accounts payable	(574)	(9,845)
Taxes accrued	(26,556)	(24,280)
Interest accrued	2,093	(4,767)
Deferred fuel costs	47,569	9,826
Other working capital accounts	533	(8,348)
Changes in provisions for estimated losses	(3,099)	7,894
Changes in other regulatory assets	(923)	26,060
Increase (Decrease) in Regulatory Liabilities	(16,615)	(139,063)
Changes in pensions and other postretirement liabilities	(6,930)	(15,987)
Other Noncash Income (Expense)	(4,387)	125,637
Net cash flow provided by operating activities	203,439	218,024
INVESTING ACTIVITIES
Construction/capital expenditures	(314,622)	(275,189)
Allowance for equity funds used during construction	6,341	6,351
Change in money pool receivable - net	32,481	1,633
Decrease (increase) in other investments	(507)	(960)
Net cash flow used in investing activities	(276,307)	(268,165)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	292,763	0
Retirement of long-term debt	(150,000)	0
Change in money pool payable - net	0	33,816
Dividends paid:
Preferred stock	0	(715)
Other	(7,913)	10,989
Net cash flow provided by financing activities	134,850	44,090
Net increase in cash and cash equivalents	61,982	(6,051)
Cash and cash equivalents at beginning of period	36,954	6,096
Cash and cash equivalents at end of period	98,936	45
Cash paid / (received) during the period for:
Interest - net of amount capitalized	41,753	44,781
Entergy New Orleans [Member]
OPERATING ACTIVITIES
Consolidated net income	46,934	50,558
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	43,146	41,756
Deferred income taxes, investment tax credits, and non-current taxes accrued	20,427	25,605
Changes in working capital:
Receivables	(14,741)	(15,310)
Fuel inventory	(374)	495
Accounts payable	(11,654)	8,868
Taxes accrued	242	(8,743)
Interest accrued	14	564
Deferred fuel costs	8,328	(59)
Other working capital accounts	(8,737)	(5,062)
Changes in provisions for estimated losses	1,423	417
Changes in other regulatory assets	(14,435)	19,068
Increase (Decrease) in Regulatory Liabilities	(15,371)	(5,353)
Changes in pensions and other postretirement liabilities	(5,784)	(12,956)
Other Noncash Income (Expense)	28,015	479
Net cash flow provided by operating activities	77,433	100,327
INVESTING ACTIVITIES
Construction/capital expenditures	(162,177)	(142,585)
Allowance for equity funds used during construction	7,769	3,762
Change in money pool receivable - net	22,016	10,607
Payments to storm reserve escrow account	(1,382)	(905)
Receipts from storm reserve escrow account	0	3
Changes in securitization account	(3,043)	(4,115)
Net cash flow used in investing activities	(136,817)	(133,233)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	0	59,590
Retirement of long-term debt	(5,420)	(5,342)
Change in money pool payable - net	46,318	0
Dividends paid:
Common stock	0	(23,750)
Other	(1,165)	2,587
Net cash flow provided by financing activities	39,733	33,085
Net increase in cash and cash equivalents	(19,651)	179
Cash and cash equivalents at beginning of period	19,677	32,741
Cash and cash equivalents at end of period	26	32,920
Cash paid / (received) during the period for:
Interest - net of amount capitalized	17,211	14,584
Income taxes	(4,899)	0
Entergy Texas [Member]
OPERATING ACTIVITIES
Consolidated net income	133,502	113,985
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	113,071	93,272
Deferred income taxes, investment tax credits, and non-current taxes accrued	21,898	640
Changes in working capital:
Receivables	21,578	(40,287)
Fuel inventory	(1,476)	1,045
Accounts payable	(58,792)	(12,864)
Taxes accrued	3,545	24,476
Interest accrued	(11,478)	(6,084)
Deferred fuel costs	(6,588)	(33,734)
Other working capital accounts	(13,740)	891
Changes in provisions for estimated losses	(3,470)	1,006
Changes in other regulatory assets	63,793	64,311
Increase (Decrease) in Regulatory Liabilities	(83,674)	15,313
Changes in pensions and other postretirement liabilities	(7,209)	(20,999)
Other Noncash Income (Expense)	3,921	(3,294)
Net cash flow provided by operating activities	174,881	197,677
INVESTING ACTIVITIES
Construction/capital expenditures	(622,342)	(291,118)
Allowance for equity funds used during construction	19,029	5,820
Proceeds from Sale of Other Assets, Investing Activities	0	3,753
Change in money pool receivable - net	(8,299)	43,686
Changes in securitization account	8,535	4,009
Net cash flow used in investing activities	(603,077)	(233,850)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	986,477	0
Proceeds from Issuance of Preferred Stock and Preference Stock	33,486	0
Retirement of long-term debt	(563,246)	(60,500)
Change in money pool payable - net	(22,389)	0
Dividends paid:
Other	(1,410)	1,657
Net cash flow provided by financing activities	520,418	(58,843)
Net increase in cash and cash equivalents	92,222	(95,016)
Cash and cash equivalents at beginning of period	56	115,513
Cash and cash equivalents at end of period	92,278	20,497
Cash paid / (received) during the period for:
Interest - net of amount capitalized	73,752	69,669
Income taxes	2,292	(624)
Proceeds from Contributions from Parent	87,500	0
System Energy [Member]
OPERATING ACTIVITIES
Consolidated net income	73,081	68,667
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	163,069	133,877
Deferred income taxes, investment tax credits, and non-current taxes accrued	(2,426)	14,159
Changes in working capital:
Receivables	(7,456)	20,806
Accounts payable	2,935	22,637
Taxes accrued	14,579	(1,017)
Interest accrued	(1,478)	2,311
Other working capital accounts	3,411	(52,524)
Changes in other regulatory assets	(9,121)	(4,773)
Increase (Decrease) in Regulatory Liabilities	90,118	(36,119)
Changes in pensions and other postretirement liabilities	(5,013)	(11,629)
Other Noncash Income (Expense)	(97,024)	(24,839)
Net cash flow provided by operating activities	224,675	131,556
INVESTING ACTIVITIES
Construction/capital expenditures	(92,228)	(166,458)
Allowance for equity funds used during construction	5,518	7,032
Change in money pool receivable - net	92,347	95,302
Nuclear fuel purchases	(2,046)	(110,485)
Payments for Nuclear Fuel	(2,046)	(110,485)
Proceeds from sale of nuclear fuel	26,272	12,867
Proceeds from nuclear decommissioning trust fund sales	348,606	357,209
Investment in nuclear decommissioning trust funds	(362,573)	(365,040)
Net cash flow used in investing activities	15,896	(169,573)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	1,007,775	211,985
Retirement of long-term debt	(1,069,206)	(124,304)
Changes in credit borrowings and commercial paper - net	0	(17,830)
Dividends paid:
Common stock	(110,500)	(64,480)
Net cash flow provided by financing activities	(171,931)	5,371
Net increase in cash and cash equivalents	68,640	(32,646)
Cash and cash equivalents at beginning of period	95,685	287,187
Cash and cash equivalents at end of period	164,325	254,541
Cash paid / (received) during the period for:
Interest - net of amount capitalized	$ 21,052	$ 10,308

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018	Dec. 31, 2017
Cash and cash equivalents:
Cash	$ 70,395	$ 56,690
Temporary cash investments	885,436	424,285
Total cash and cash equivalents	955,831	480,975	$ 987,981	$ 781,273
Securitization recovery trust account	55,000	51,000
Accounts receivable:
Customer	732,763	558,494
Allowance for doubtful accounts	(7,987)	(7,322)
Other	132,547	167,722
Accrued unbilled revenues	481,048	395,511
Total accounts receivable	1,338,371	1,114,405
Deferred fuel costs	0	27,251
Fuel inventory - at average cost	131,703	117,304
Public Utilities, Inventory	803,843	752,843
Deferred nuclear refueling outage costs	173,229	230,960
Prepaid Expense and Other Assets, Current	258,695	234,326
TOTAL	3,661,672	2,958,064
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	6,128,647	6,920,164
Non-utility property - at cost (less accumulated depreciation)	326,704	304,382
Other	448,140	437,265
TOTAL	6,903,491	7,661,811
PROPERTY, PLANT, AND EQUIPMENT
Electric	52,705,142	49,831,486
Natural gas	533,217	496,150
Construction work in progress	2,871,054	2,888,639
Nuclear fuel	707,198	861,272
TOTAL PROPERTY, PLANT, AND EQUIPMENT	56,816,611	54,077,547
Less - accumulated depreciation and amortization	22,695,886	22,103,101
PROPERTY, PLANT, AND EQUIPMENT - NET	34,120,725	31,974,446
Regulatory assets:
Other regulatory assets	4,839,357	4,746,496
Deferred Fuel Cost Non Current	239,793	239,496
Goodwill	377,172	377,172
Deferred Income Tax Assets, Net	67,438	54,593
Other	296,620	262,988
Deferred Costs and Other Assets	5,820,380	5,680,745
TOTAL ASSETS	50,506,268	48,275,066
CURRENT LIABILITIES
Currently maturing long-term debt	520,012	650,009
Short-term borrowings	1,917,788	1,942,339
Accounts payable	1,328,631	1,496,058
Customer deposits	409,090	411,505
Taxes Payable, Current	251,821	254,241
Interest accrued	190,877	193,192
Deferred fuel costs	115,761	52,396
Pension and other postretirement liabilities	57,374	61,240
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	117,575	248,127
Other	194,117	134,437
TOTAL	5,103,046	5,443,544
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	4,552,456	4,107,152
Accumulated deferred investment tax credits	206,837	213,101
Regulatory liability for income taxes - net	1,677,707	1,817,021
Other regulatory liabilities	1,871,005	1,620,254
Decommissioning and asset retirement cost liabilities	6,068,323	6,355,543
Loss Contingency Accrual	528,172	514,107
Pension and other postretirement liabilities	2,487,906	2,616,085
Long-term debt	16,938,014	15,518,303
Deferred Credits and Other Liabilities	783,330	1,006,249
TOTAL	35,113,750	33,767,815
Subsidiaries' preferred stock without sinking fund	219,411	219,402
Common Shareholders' Equity:
Common Stock, Value, Issued	2,700	2,616
Additional Paid in Capital, Common Stock	6,553,009	5,951,431
Accumulated other comprehensive loss	(419,772)	(557,173)	(632,126)	(23,531)
Less - treasury stock, at cost	5,158,625	5,273,719
TOTAL	10,035,061	8,844,305
Stockholders' Equity Attributable to Noncontrolling Interest	35,000	0
Retained Earnings (Accumulated Deficit)	9,057,749	8,721,150
TOTAL	10,070,061	8,844,305	8,412,712	7,992,515
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	50,506,268	48,275,066
Entergy Arkansas [Member]
Cash and cash equivalents:
Cash	410	118
Temporary cash investments	76,659	1
Total cash and cash equivalents	77,069	119	221,782	6,216
Securitization recovery trust account	7,904	4,666
Accounts receivable:
Customer	160,955	94,348
Allowance for doubtful accounts	(1,423)	(1,264)
Associated companies	45,499	48,184
Other	48,569	64,393
Accrued unbilled revenues	137,444	108,092
Total accounts receivable	391,044	313,753
Deferred fuel costs	0	19,235
Fuel inventory - at average cost	28,498	23,148
Public Utilities, Inventory	207,541	196,314
Deferred nuclear refueling outage costs	33,581	78,966
Prepaid Expense and Other Assets, Current	17,447	14,553
TOTAL	763,084	650,754
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,045,826	912,049
Other	5,476	5,480
TOTAL	1,051,302	917,529
PROPERTY, PLANT, AND EQUIPMENT
Electric	12,041,822	11,611,041
Construction work in progress	299,195	243,731
Nuclear fuel	186,731	220,602
TOTAL PROPERTY, PLANT, AND EQUIPMENT	12,527,748	12,075,374
Less - accumulated depreciation and amortization	4,985,276	4,864,818
PROPERTY, PLANT, AND EQUIPMENT - NET	7,542,472	7,210,556
Regulatory assets:
Other regulatory assets	1,590,726	1,534,977
Deferred Fuel Cost Non Current	67,591	67,294
Other	21,441	20,486
Deferred Costs and Other Assets	1,679,758	1,622,757
TOTAL ASSETS	11,036,616	10,401,596
CURRENT LIABILITIES
Associated companies accounts payable	55,971	251,768
Accounts payable	195,783	187,387
Customer deposits	101,349	99,053
Taxes Payable, Current	38,281	56,889
Interest accrued	39,099	18,893
Deferred fuel costs	33,530	0
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	33,692	99,316
Other	48,516	23,943
TOTAL	546,221	737,249
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	1,172,542	1,085,545
Accumulated deferred investment tax credits	32,002	32,903
Regulatory liability for income taxes - net	480,573	505,748
Other regulatory liabilities	526,004	402,668
Decommissioning and asset retirement cost liabilities	1,224,936	1,048,428
Loss Contingency Accrual	57,820	48,979
Pension and other postretirement liabilities	287,086	313,295
Long-term debt	3,538,384	3,225,759
Deferred Credits and Other Liabilities	63,809	17,919
TOTAL	7,383,156	6,681,244
Common Shareholders' Equity:
Members' Equity	3,107,239	2,983,103
TOTAL	3,107,239	2,983,103	2,973,384	2,376,754
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	11,036,616	10,401,596
Entergy Louisiana [Member]
Cash and cash equivalents:
Cash	224	252
Temporary cash investments	127,821	43,112
Total cash and cash equivalents	128,045	43,364	213,585	35,907
Securitization recovery trust account	10,100	3,600
Accounts receivable:
Customer	258,090	199,903
Allowance for doubtful accounts	(2,154)	(1,813)
Associated companies	81,906	123,363
Other	46,282	60,879
Accrued unbilled revenues	194,753	167,052
Total accounts receivable	578,877	549,384
Fuel inventory - at average cost	36,170	34,418
Public Utilities, Inventory	344,207	324,627
Deferred nuclear refueling outage costs	70,456	24,406
Prepaid Expense and Other Assets, Current	47,519	38,715
TOTAL	1,205,274	1,014,914
Investments in and Advances to Affiliates, at Fair Value	1,390,587	1,390,587
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,485,569	1,284,996
Non-utility property - at cost (less accumulated depreciation)	308,095	286,555
Storm Reserve Escrow Account	294,538	289,525
Other	13,923	14,927
TOTAL	3,492,712	3,266,590
PROPERTY, PLANT, AND EQUIPMENT
Electric	22,283,456	20,532,312
Natural gas	230,416	211,421
Construction work in progress	1,325,784	1,864,582
Nuclear fuel	291,404	298,022
TOTAL PROPERTY, PLANT, AND EQUIPMENT	24,131,060	22,906,337
Less - accumulated depreciation and amortization	9,018,154	8,837,596
PROPERTY, PLANT, AND EQUIPMENT - NET	15,112,906	14,068,741
Regulatory assets:
Other regulatory assets	1,208,712	1,105,077
Deferred Fuel Cost Non Current	168,122	168,122
Other	27,297	28,371
Deferred Costs and Other Assets	1,404,131	1,301,570
TOTAL ASSETS	21,215,023	19,651,815
CURRENT LIABILITIES
Currently maturing long-term debt	70,002	2
Associated companies accounts payable	86,781	102,749
Accounts payable	338,724	390,367
Customer deposits	152,627	155,314
Taxes Payable, Current	109,778	30,868
Interest accrued	88,552	83,450
Deferred fuel costs	19,952	31,411
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	33,231	31,457
Other	71,608	49,202
TOTAL	971,255	874,820
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	2,414,508	2,226,721
Accumulated deferred investment tax credits	113,346	116,999
Regulatory liability for income taxes - net	523,697	581,001
Other regulatory liabilities	778,199	748,784
Decommissioning and asset retirement cost liabilities	1,478,951	1,280,272
Loss Contingency Accrual	320,503	310,755
Pension and other postretirement liabilities	627,155	643,171
Long-term debt	7,274,158	6,805,766
Deferred Credits and Other Liabilities	402,296	160,608
TOTAL	13,932,813	12,874,077
Common Shareholders' Equity:
Accumulated other comprehensive loss	(9,060)	(6,153)
Members' Equity	6,320,015	5,909,071
TOTAL	6,310,955	5,902,918	5,761,778	5,308,804
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	21,215,023	19,651,815
Entergy Mississippi [Member]
Cash and cash equivalents:
Cash	11	11
Temporary cash investments	98,925	36,943
Total cash and cash equivalents	98,936	36,954	45	6,096
Accounts receivable:
Customer	98,245	73,205
Allowance for doubtful accounts	(615)	(563)
Associated companies	19,217	51,065
Other	10,173	8,647
Accrued unbilled revenues	60,867	50,171
Total accounts receivable	187,887	182,525
Deferred fuel costs	0	8,016
Fuel inventory - at average cost	15,803	11,931
Public Utilities, Inventory	51,049	47,255
Prepaid Expense and Other Assets, Current	8,694	9,365
TOTAL	362,369	296,046
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,564	4,576
Escrow accounts	32,953	32,447
TOTAL	37,517	37,023
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,981,082	4,780,720
Construction work in progress	177,221	128,149
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,158,303	4,908,869
Less - accumulated depreciation and amortization	1,681,597	1,641,821
PROPERTY, PLANT, AND EQUIPMENT - NET	3,476,706	3,267,048
Regulatory assets:
Other regulatory assets	343,972	343,049
Other	12,161	3,638
Deferred Costs and Other Assets	356,133	346,687
TOTAL ASSETS	4,232,725	3,946,804
CURRENT LIABILITIES
Currently maturing long-term debt	0	150,000
Associated companies accounts payable	41,323	42,928
Accounts payable	81,260	79,117
Customer deposits	86,295	85,085
Taxes Payable, Current	50,996	77,552
Interest accrued	22,324	20,231
Deferred fuel costs	39,553	0
Other	17,717	7,526
TOTAL	339,468	462,439
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	591,105	551,869
Accumulated deferred investment tax credits	10,066	10,186
Regulatory liability for income taxes - net	239,630	246,402
Other regulatory liabilities	23,779	33,622
Decommissioning and asset retirement cost liabilities	9,594	9,206
Loss Contingency Accrual	48,043	51,142
Pension and other postretirement liabilities	86,036	93,100
Long-term debt	1,469,454	1,175,750
Deferred Credits and Other Liabilities	25,022	20,862
TOTAL	2,502,729	2,192,139
Common Shareholders' Equity:
Members' Equity	1,390,528	1,292,226
TOTAL	1,390,528	1,292,226	1,288,973	1,177,870
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	4,232,725	3,946,804
Entergy New Orleans [Member]
Cash and cash equivalents:
Cash	26	26
Temporary cash investments	0	19,651
Total cash and cash equivalents	26	19,677	32,920	32,741
Securitization recovery trust account	5,268	2,224
Accounts receivable:
Customer	57,173	43,890
Allowance for doubtful accounts	(3,116)	(3,222)
Associated companies	2,541	27,938
Other	4,954	4,090
Accrued unbilled revenues	22,776	18,907
Total accounts receivable	84,328	91,603
Fuel inventory - at average cost	1,907	1,533
Public Utilities, Inventory	12,865	12,133
Prepaid Expense and Other Assets, Current	10,655	6,905
TOTAL	115,049	134,075
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	1,016	1,016
Storm Reserve Escrow Account	82,236	80,853
TOTAL	83,252	81,869
PROPERTY, PLANT, AND EQUIPMENT
Electric	1,430,352	1,364,091
Natural gas	302,801	284,728
Construction work in progress	196,842	146,668
TOTAL PROPERTY, PLANT, AND EQUIPMENT	1,929,995	1,795,487
Less - accumulated depreciation and amortization	699,525	670,135
PROPERTY, PLANT, AND EQUIPMENT - NET	1,230,470	1,125,352
Regulatory assets:
Other regulatory assets	244,231	229,796
Deferred Fuel Cost Non Current	4,080	4,080
Other	1,749	1,416
Deferred Costs and Other Assets	250,060	235,292
TOTAL ASSETS	1,678,831	1,576,588
CURRENT LIABILITIES
Notes Payable, Related Parties, Current	1,979	1,979
Associated companies accounts payable	85,485	43,416
Accounts payable	37,394	36,686
Customer deposits	28,515	28,667
Taxes Payable, Current	4,310	4,068
Interest accrued	6,380	6,366
Deferred fuel costs	9,616	1,288
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	15,439	25,301
Other	7,182	9,521
TOTAL	196,300	157,292
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	349,600	323,595
Accumulated deferred investment tax credits	2,153	2,219
Regulatory liability for income taxes - net	52,705	60,249
Decommissioning and asset retirement cost liabilities	3,463	3,291
Loss Contingency Accrual	88,017	86,594
Long-term debt	462,273	467,358
Notes Payable, Related Parties, Noncurrent	14,367	14,367
Deferred Credits and Other Liabilities	18,069	16,673
TOTAL	990,647	974,346
Common Shareholders' Equity:
Members' Equity	491,884	444,950
TOTAL	491,884	444,950	442,356	415,548
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	1,678,831	1,576,588
Entergy Texas [Member]
Cash and cash equivalents:
Cash	25	26
Temporary cash investments	92,253	30
Total cash and cash equivalents	92,278	56	20,497	115,513
Securitization recovery trust account	31,649	40,185
Accounts receivable:
Customer	88,557	69,714
Allowance for doubtful accounts	(680)	(461)
Associated companies	24,124	64,441
Other	6,770	12,275
Accrued unbilled revenues	65,207	51,288
Total accounts receivable	183,978	197,257
Fuel inventory - at average cost	44,143	42,667
Public Utilities, Inventory	43,774	41,883
Prepaid Expense and Other Assets, Current	22,266	15,903
TOTAL	418,088	337,951
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	413	448
Non-utility property - at cost (less accumulated depreciation)	376	376
Other	19,863	19,218
TOTAL	20,652	20,042
PROPERTY, PLANT, AND EQUIPMENT
Electric	5,028,850	4,773,984
Construction work in progress	663,465	325,193
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,692,315	5,099,177
Less - accumulated depreciation and amortization	1,745,046	1,684,569
PROPERTY, PLANT, AND EQUIPMENT - NET	3,947,269	3,414,608
Regulatory assets:
Other regulatory assets	534,255	598,048
Other	32,861	29,371
Deferred Costs and Other Assets	567,116	627,419
TOTAL ASSETS	4,953,125	4,400,020
CURRENT LIABILITIES
Currently maturing long-term debt	0	500,000
Associated companies accounts payable	45,090	119,371
Accounts payable	169,788	150,679
Customer deposits	40,304	43,387
Taxes Payable, Current	57,058	53,513
Interest accrued	12,877	24,355
Deferred fuel costs	13,109	19,697
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	35,213	87,627
Other	8,786	6,353
TOTAL	382,225	1,004,982
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	581,310	552,535
Accumulated deferred investment tax credits	10,713	11,176
Regulatory liability for income taxes - net	236,463	264,623
Other regulatory liabilities	44,784	47,884
Decommissioning and asset retirement cost liabilities	7,526	7,222
Loss Contingency Accrual	10,386	13,856
Long-term debt	1,938,303	1,013,735
Deferred Credits and Other Liabilities	64,635	61,605
TOTAL	2,894,120	1,972,636
Common Shareholders' Equity:
Common Stock, Value, Issued	49,452	49,452
Additional Paid in Capital, Common Stock	682,980	596,994
TOTAL	1,641,780	1,422,402
Stockholders' Equity Attributable to Noncontrolling Interest	35,000	0
Retained Earnings (Accumulated Deficit)	909,348	775,956
TOTAL	1,676,780	1,422,402	1,374,152	1,260,167
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	4,953,125	4,400,020
System Energy [Member]
Cash and cash equivalents:
Cash	79	68
Temporary cash investments	164,246	95,617
Total cash and cash equivalents	164,325	95,685	254,541	287,187
Accounts receivable:
Associated companies	62,740	148,571
Other	6,330	5,390
Total accounts receivable	69,070	153,961
Public Utilities, Inventory	111,927	97,225
Deferred nuclear refueling outage costs	20,253	44,424
Prepaid Expense and Other Assets, Current	9,040	2,985
Prepaid Taxes	0	5,415
TOTAL	374,615	399,695
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,002,261	869,543
TOTAL	1,002,261	869,543
PROPERTY, PLANT, AND EQUIPMENT
Electric	5,036,030	5,036,116
Construction work in progress	141,858	70,156
Nuclear fuel	158,745	234,889
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,336,633	5,341,161
Less - accumulated depreciation and amortization	3,273,504	3,212,080
PROPERTY, PLANT, AND EQUIPMENT - NET	2,063,129	2,129,081
Regulatory assets:
Other regulatory assets	455,492	446,371
Other	3,759	4,124
Deferred Costs and Other Assets	459,251	450,495
TOTAL ASSETS	3,899,256	3,848,814
CURRENT LIABILITIES
Currently maturing long-term debt	10	6
Associated companies accounts payable	11,475	11,031
Accounts payable	61,391	47,565
Taxes Payable, Current	9,164	0
Interest accrued	11,817	13,295
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	0	4,426
Other	2,829	2,832
TOTAL	96,686	79,155
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	811,875	805,296
Accumulated deferred investment tax credits	37,714	38,673
Regulatory liability for income taxes - net	144,639	158,998
Other regulatory liabilities	490,790	381,887
Decommissioning and asset retirement cost liabilities	922,663	896,000
Pension and other postretirement liabilities	93,626	98,639
Long-term debt	569,991	630,744
Deferred Credits and Other Liabilities	31,493	22,224
TOTAL	3,102,791	3,032,461
Common Shareholders' Equity:
Common Stock, Value, Issued	601,850	601,850
Retained Earnings (Accumulated Deficit)	97,929	135,348
TOTAL	699,779	737,198	$ 714,996	$ 710,809
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$ 3,899,256	$ 3,848,814

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Securitization property	$ 268,177	$ 360,790
Securitization bonds	$ 338,408	$ 423,858
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	500,000,000	500,000,000
Common stock, shares issued	270,035,180	261,587,009
Treasury stock, shares	70,947,950	72,530,866
Entergy Arkansas [Member]
Securitization property	$ 4,596	$ 14,329
Securitization bonds	14,016	20,898
Entergy Louisiana [Member]
Securitization property	32,939	49,753
Securitization bonds	45,386	55,682
Entergy New Orleans [Member]
Securitization property	52,085	60,453
Securitization bonds	58,382	63,620
Entergy Texas [Member]
Securitization property	178,558	236,336
Securitization bonds	$ 220,625	$ 283,659
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares issued	46,525,000	46,525,000
Common stock, shares outstanding	46,525,000	46,525,000
System Energy [Member]
Common stock, shares authorized	1,000,000	1,000,000
Common stock, shares issued	789,350	789,350
Common stock, shares outstanding	789,350	789,350

Consolidated Statements Of Chan

Consolidated Statements Of Changes In Equity - USD ($) $ in Thousands	Total	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	$ 7,992,515	$ 0	$ 5,433,433	$ 7,977,702	$ (23,531)	$ 2,548	$ (5,397,637)	$ 1,260,167	$ 0	$ 596,994	$ 613,721	$ 49,452	$ 1,177,870	$ 2,376,754	$ 5,308,804	$ 5,355,204	$ (46,400)	$ 415,548	$ 710,809	$ 52,459	$ 658,350
Consolidated net income	136,200	3,439	0	132,761	0	0	0	17,350	0	0	17,350	0	22,843	36,255	111,593	111,593	0	10,882	22,308	22,308	0
Dividends, Common Stock, Cash	(160,887)	0	0	(160,887)	0	0	0											(6,250)	(63,240)	(6,740)	(56,500)
Dividends, Preferred Stock, Cash													(238)	(357)
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(3,439)	(3,439)	0	0	0	0	0
Other comprehensive income (loss)	79,145	0	0	0	79,145	0	0								(501)	0	(501)
Common stock issuances related to stock plans	(4,307)	0	16,170	0	0	0	(20,477)
Other															24	24	0
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect	(16,538)	0	0	(32,043)	15,505	0	0								(3,787)	6,262	(10,049)
Consolidated net income	924,877							113,985					111,818	247,701	514,260			50,558	68,667
Proceeds from Contributions from Parent								0						350,000
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(10,317)												(715)	(1,071)
Other comprehensive income (loss)	8,517														(1,502)
Payments for Repurchase of Preferred Stock and Preference Stock	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	7,974,943	0	5,417,263	8,493,790	(561,498)	2,548	(5,377,160)	1,277,517	0	596,994	631,071	49,452	1,200,475	2,412,652	5,416,133	5,473,083	(56,950)	420,180	669,877	68,027	601,850
Consolidated net income	248,860	3,439	0	245,421	0	0	0	30,789	0	0	30,789	0	38,242	82,556	184,358	184,358	0	18,269	23,387	23,387	0
Proceeds from Contributions from Parent														350,000
Dividends, Common Stock, Cash	(160,935)	0	0	(160,935)	0	0	0								(56,000)	(56,000)	0	(8,250)
Dividends, Preferred Stock, Cash													(239)	(357)
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(3,439)	(3,439)	0	0	0	0	0
Other comprehensive income (loss)	(52,144)	0	0	0	(52,144)	0	0								(501)	0	(501)
Common stock issuances related to stock plans	(15,176)	0	(12,141)	0	0	0	(3,035)
Other															(10)	(10)	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	8,022,461	0	5,429,404	8,578,276	(613,642)	2,548	(5,374,125)	1,308,306	0	596,994	661,860	49,452	1,238,478	2,844,851	5,543,980	5,601,431	(57,451)	430,199	693,264	91,414	601,850
Consolidated net income	539,818	3,439	0	536,379	0	0	0	65,846	0	0	65,846	0	50,733	128,890	218,308	218,308	0	21,407	22,972	22,972	0
Dividends, Common Stock, Cash	(161,044)	0	0	(161,044)	0	0	0											(9,250)	(1,240)	(1,240)	0
Dividends, Preferred Stock, Cash													(238)	(357)
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(3,439)	(3,439)	0	0	0	0	0
Other comprehensive income (loss)	(18,484)	0	0	0	(18,484)	0	0								(500)	0	(500)
Common stock issuances related to stock plans	(33,400)	0	(12,292)	0	0	0	(21,108)
Other															(10)	(10)	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	8,412,712	0	5,441,696	8,953,611	(632,126)	2,548	(5,353,017)	1,374,152	0	596,994	727,706	49,452	1,288,973	2,973,384	5,761,778	5,819,729	(57,951)	442,356	714,996	113,146	601,850
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	8,844,305	0	5,951,431	8,721,150	(557,173)	2,616	(5,273,719)	1,422,402	0	596,994	775,956	49,452	1,292,226	2,983,103	5,902,918	5,909,071	(6,153)	444,950	737,198	135,348	601,850
Consolidated net income	258,646	4,109	0	254,537	0	0	0	21,342	0	0	21,342	0	15,398	39,121	127,633	127,633	0	9,023	23,578	23,578	0
Dividends, Common Stock, Cash	(172,591)	0	0	(172,591)	0	0	0								(49,000)	(49,000)	0		(45,500)	(45,500)	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(4,109)	(4,109)	0	0	0	0	0
Other comprehensive income (loss)	12,827	0	0	0	12,827	0	0								(969)	0	(969)
Common stock issuances related to stock plans	(31,289)	0	31,248	0	0	0	(62,537)
Other															(11)	(11)	0
Consolidated net income	868,639							133,502					98,302	239,136	565,977			46,934	73,081
Proceeds from Contributions from Parent								87,500						0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(12,328)												0	0
Other comprehensive income (loss)	144,207														(2,907)
Payments for Repurchase of Preferred Stock and Preference Stock	50,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	8,970,367	0	5,920,183	8,809,902	(551,152)	2,616	(5,211,182)	1,443,744	0	596,994	797,298	49,452	1,307,624	3,022,224	5,980,571	5,987,693	(7,122)	453,973	715,276	113,426	601,850
Consolidated net income	240,533	4,109	0	236,424	0	0	0	38,936	0	0	38,936	0	26,667	50,299	183,084	183,084	0	13,003	24,472	24,472	0
Dividends, Common Stock, Cash	(172,861)	0	0	(172,861)	0	0	0							(115,000)	(53,000)	(53,000)	0		(42,500)	(42,500)	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(4,109)	(4,109)	0	0	0	0	0
Other comprehensive income (loss)	120,748	0	0	0	120,748	0	0								(969)	0	(969)
Stock Issued During Period, Value, New Issues	(607,650)	0	(607,566)	0	0	(84)	0
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs	(7)	0	(7)	0	0	0	0
Common stock issuances related to stock plans	(35,182)	0	(11,791)	0	0	0	(23,391)
Other															(14)	(14)	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	9,797,503	0	6,539,533	8,873,465	(430,404)	2,700	(5,187,791)	1,482,680	0	596,994	836,234	49,452	1,334,291	2,957,523	6,109,672	6,117,763	(8,091)	466,976	697,248	95,398	601,850
Consolidated net income	369,459	4,219	0	365,240	0	0	0	73,224	0	0	73,224	0	56,237	149,716	255,260	255,260	0	24,908	25,031	25,031	0
Proceeds from Contributions from Parent								87,500	0	87,500	0	0
Dividends, Common Stock, Cash	(180,956)	0	0	(180,956)	0	0	0	(110)	0	0	(110)	0			(53,000)	(53,000)	0		(22,500)	(22,500)	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(4,219)	(4,219)	0	0	0	0	0
Other comprehensive income (loss)	10,632	0	0	0	10,632	0	0								(969)	0	(969)
Stock Issued During Period, Value, New Issues	(35,000)	(35,000)	0	0	0	0	0	(33,486)	(35,000)	1,514	0	0
Common stock issuances related to stock plans	(42,642)	0	(13,476)	0	0	0	(29,166)
Other															(8)	(8)	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 10,070,061	$ 35,000	$ 6,553,009	$ 9,057,749	$ (419,772)	$ 2,700	$ (5,158,625)	$ 1,676,780	$ 35,000	$ 682,980	$ 909,348	$ 49,452	$ 1,390,528	$ 3,107,239	$ 6,310,955	$ 6,320,015	$ (9,060)	$ 491,884	$ 699,779	$ 97,929	$ 601,850

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Net income	$ 369,459	$ 539,818	$ 868,639	$ 924,877
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss)	(20,103)	(32,004)	62,453	(1,645)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	25,464	15,265	48,510	47,404
Net unrealized investment gains	5,271	(1,745)	33,244	(37,242)
Other comprehensive income (loss)	10,632	(18,484)	144,207	8,517
Total comprehensive income	380,091	521,334	1,012,846	933,394
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	4,219	3,439	12,438	10,317
Comprehensive Income Attributable to Entergy Corporation	375,872	517,895	1,000,408	923,077
Entergy Louisiana [Member]
Net income	255,260	218,308	565,977	514,260
Other comprehensive income (loss)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	(969)	(500)	(2,907)	(1,502)
Other comprehensive income (loss)	(969)	(500)	(2,907)	(1,502)
Total comprehensive income	$ 254,291	$ 217,808	$ 563,070	$ 512,758

Consolidated Statements Of Co_2

Consolidated Statements Of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Tax	$ (5,343)	$ (8,517)	$ 14,547	$ (480)
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	6,760	4,126	13,086	12,919
Other Comprehensive Income (Loss), Securities, Available-for-sale, Tax	1,303	(825)	17,472	1,708
Entergy Louisiana [Member]
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	$ (342)	$ (177)	$ (1,026)	$ (530)

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2019
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory 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. Pilgrim NRC Oversight and Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s shutdown of Pilgrim. In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In June 2019, following permanent defueling of the reactor, Pilgrim was removed from the NRC’s Reactor Oversight Process and is now subject to the NRC’s normal decommissioning inspection program. In August 2019 the NRC approved the transfer of the Pilgrim operating license from Entergy to Holtec and the transaction closed on August 26, 2019. See Note 16 to the financial statements herein for further discussion of the sale of Pilgrim. 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. The following is an update to that discussion. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously capitalized. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. The following is an update to that discussion. Capital Funds Agreement (Entergy Corporation and System Energy) Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35%
Entergy Arkansas [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory 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. Pilgrim NRC Oversight and Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s shutdown of Pilgrim. In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In June 2019, following permanent defueling of the reactor, Pilgrim was removed from the NRC’s Reactor Oversight Process and is now subject to the NRC’s normal decommissioning inspection program. In August 2019 the NRC approved the transfer of the Pilgrim operating license from Entergy to Holtec and the transaction closed on August 26, 2019. See Note 16 to the financial statements herein for further discussion of the sale of Pilgrim. 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. The following is an update to that discussion. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously capitalized. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. The following is an update to that discussion. Capital Funds Agreement (Entergy Corporation and System Energy) Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35%
Entergy Louisiana [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory 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. Pilgrim NRC Oversight and Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s shutdown of Pilgrim. In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In June 2019, following permanent defueling of the reactor, Pilgrim was removed from the NRC’s Reactor Oversight Process and is now subject to the NRC’s normal decommissioning inspection program. In August 2019 the NRC approved the transfer of the Pilgrim operating license from Entergy to Holtec and the transaction closed on August 26, 2019. See Note 16 to the financial statements herein for further discussion of the sale of Pilgrim. 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. The following is an update to that discussion. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously capitalized. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. The following is an update to that discussion. Capital Funds Agreement (Entergy Corporation and System Energy) Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35%
Entergy Mississippi [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory 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. Pilgrim NRC Oversight and Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s shutdown of Pilgrim. In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In June 2019, following permanent defueling of the reactor, Pilgrim was removed from the NRC’s Reactor Oversight Process and is now subject to the NRC’s normal decommissioning inspection program. In August 2019 the NRC approved the transfer of the Pilgrim operating license from Entergy to Holtec and the transaction closed on August 26, 2019. See Note 16 to the financial statements herein for further discussion of the sale of Pilgrim. 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. The following is an update to that discussion. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously capitalized. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. The following is an update to that discussion. Capital Funds Agreement (Entergy Corporation and System Energy) Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35%
Entergy New Orleans [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory 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. Pilgrim NRC Oversight and Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s shutdown of Pilgrim. In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In June 2019, following permanent defueling of the reactor, Pilgrim was removed from the NRC’s Reactor Oversight Process and is now subject to the NRC’s normal decommissioning inspection program. In August 2019 the NRC approved the transfer of the Pilgrim operating license from Entergy to Holtec and the transaction closed on August 26, 2019. See Note 16 to the financial statements herein for further discussion of the sale of Pilgrim. 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. The following is an update to that discussion. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously capitalized. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. The following is an update to that discussion. Capital Funds Agreement (Entergy Corporation and System Energy) Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35%
Entergy Texas [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory 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. Pilgrim NRC Oversight and Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s shutdown of Pilgrim. In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In June 2019, following permanent defueling of the reactor, Pilgrim was removed from the NRC’s Reactor Oversight Process and is now subject to the NRC’s normal decommissioning inspection program. In August 2019 the NRC approved the transfer of the Pilgrim operating license from Entergy to Holtec and the transaction closed on August 26, 2019. See Note 16 to the financial statements herein for further discussion of the sale of Pilgrim. 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. The following is an update to that discussion. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously capitalized. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. The following is an update to that discussion. Capital Funds Agreement (Entergy Corporation and System Energy) Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35%
System Energy [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory 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. Pilgrim NRC Oversight and Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s shutdown of Pilgrim. In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In June 2019, following permanent defueling of the reactor, Pilgrim was removed from the NRC’s Reactor Oversight Process and is now subject to the NRC’s normal decommissioning inspection program. In August 2019 the NRC approved the transfer of the Pilgrim operating license from Entergy to Holtec and the transaction closed on August 26, 2019. See Note 16 to the financial statements herein for further discussion of the sale of Pilgrim. 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. The following is an update to that discussion. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously capitalized. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. The following is an update to that discussion. Capital Funds Agreement (Entergy Corporation and System Energy) Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35%

Rate And Regulatory Matters

Rate And Regulatory Matters	9 Months Ended
	Sep. 30, 2019
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities 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. Regulatory activity regarding the Tax Cuts and Jobs Act System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and the hearing is scheduled for March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement are challenging the treatment and amount of excess tax liabilities associated with uncertain tax positions related to nuclear decommissioning. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020. Energy Cost Recovery Rider In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million , plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million , plus interest, as compared to the LPSC staff’s recommendation of $7.3 million , plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court. Entergy Texas In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million , including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending. 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 2019 Formula Rate Plan Filing In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018. The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million , which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted. These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing. In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the proposed formula rate plan rider revenue change to $14 million . Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million . The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a write off of the $11.2 million White Bluff scrubber regulatory asset. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing Commercial operation at St. Charles Power Station commenced in May 2019. 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 St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. 2018 Formula Rate Plan Filing In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million . While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million . This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues. Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing. Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests. Investigation of Costs Billed by Entergy Services In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit. Retail Rates - Gas 2018 Rate Stabilization Plan Filing As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. Gas Rate Stabilization Plan Extension Request In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13% , resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019. Filings with the City Council (Entergy New Orleans) Retail Rates See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case. That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ( $27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5% , but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ( $36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting. Filings with the PUCT (Entergy Texas) Base Rate Case In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million . The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions . In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million . In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT. Other Filings In March 2019, Entergy Texas filed with the PUCT a request to set a new distribution cost recovery factor (DCRF) rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application. In December 2018, Entergy Texas filed with the PUCT a request to set a new transmission cost recovery factor (TCRF) rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT. In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In the initial decision, the presiding judge agreed with the Utility operating companies’ position that: (1) interest on the bandwidth payments for the 2005 test period should be accrued from June 1, 2006 until the date that the bandwidth payments for that calculation are paid, which is consistent with how the Utility operating companies performed the calculation; and (2) a portion of Entergy Louisiana’s 2001-vintage Louisiana state net operating loss accumulated deferred income tax that results from the Vidalia tax deduction should be excluded from the 2005 test period bandwidth calculation. Various participants filed briefs on exceptions and/or briefs opposing exceptions related to the initial decision, including the LPSC, the APSC, the FERC trial staff, and Entergy Services. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6 These payments were made in July 2018. In January 2019 the FERC denied the LPSC’s request for rehearing of the May 2018 order. In May 2019 the FERC accepted the July 2018 compliance filing, and the LPSC sought rehearing of that decision in June 2019. Rough Production Cost Equalization 2010 Rate Filing Based on Calendar Year 2009 Production Costs In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010. Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests. In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund. After an abeyance of the proceeding schedule, a hearing was held in March 2014 and in December 2015 the FERC issued an order. Among other things, the December 2015 order directed Entergy to submit a compliance filing. In January 2016 the LPSC, the APSC, and Entergy filed requests for rehearing of the FERC’s December 2015 order. In February 2016, Entergy submitted the compliance filing ordered in the December 2015 order. The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3) In September 2016 the FERC accepted the February 2016 compliance filing subject to a further compliance filing made in November 2016. The further compliance filing was required as a result of an order issued in September 2016 ruling on the January 2016 rehearing requests filed by the LPSC, the APSC, and Entergy. In the order addressing the rehearing requests, the FERC granted the LPSC’s rehearing request and directed that interest be calculated on the payment/receipt amounts. The FERC also granted the APSC’s and Entergy’s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation. In November 2016, Entergy submitted its compliance filing in response to the FERC’s order on rehearing. The compliance filing included a revised calculation of the bandwidth true-up payments and receipts based on 2009 test year data and interest calculations. The LPSC protested the interest calculations. I n November 2017 the FERC issued an order rejecting the November 2016 compliance filing. The FERC determined that the payments detailed in the November 2016 compliance filing did not include adequate interest for the payments from Entergy Arkansas to Entergy Louisiana because it did not include interest on the principal portion of the payment that was made in February 2016. In December 2017, Entergy recalculated the interest pursuant to the November 2017 order. As a result of the recalculations, Entergy Arkansas owed very minor payments to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. In June 2019 the FERC issued an order denying the LPSC’s rehearing request of FERC’s September 2016 order. The LPSC rehearing request asked the FERC to reverse its decision that both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes should be removed from the bandwidth calculation. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action. In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period. The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring 30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding. Complaints Against System Energy Return on Equity and Capital Structure Complaints See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 27, 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019 settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding. In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24% . For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41% . In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint). In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period. In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the ne
Entergy Arkansas [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities 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. Regulatory activity regarding the Tax Cuts and Jobs Act System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and the hearing is scheduled for March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement are challenging the treatment and amount of excess tax liabilities associated with uncertain tax positions related to nuclear decommissioning. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020. Energy Cost Recovery Rider In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million , plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million , plus interest, as compared to the LPSC staff’s recommendation of $7.3 million , plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court. Entergy Texas In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million , including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending. 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 2019 Formula Rate Plan Filing In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018. The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million , which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted. These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing. In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the proposed formula rate plan rider revenue change to $14 million . Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million . The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a write off of the $11.2 million White Bluff scrubber regulatory asset. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing Commercial operation at St. Charles Power Station commenced in May 2019. 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 St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. 2018 Formula Rate Plan Filing In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million . While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million . This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues. Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing. Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests. Investigation of Costs Billed by Entergy Services In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit. Retail Rates - Gas 2018 Rate Stabilization Plan Filing As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. Gas Rate Stabilization Plan Extension Request In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13% , resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019. Filings with the City Council (Entergy New Orleans) Retail Rates See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case. That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ( $27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5% , but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ( $36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting. Filings with the PUCT (Entergy Texas) Base Rate Case In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million . The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions . In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million . In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT. Other Filings In March 2019, Entergy Texas filed with the PUCT a request to set a new distribution cost recovery factor (DCRF) rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application. In December 2018, Entergy Texas filed with the PUCT a request to set a new transmission cost recovery factor (TCRF) rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT. In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In the initial decision, the presiding judge agreed with the Utility operating companies’ position that: (1) interest on the bandwidth payments for the 2005 test period should be accrued from June 1, 2006 until the date that the bandwidth payments for that calculation are paid, which is consistent with how the Utility operating companies performed the calculation; and (2) a portion of Entergy Louisiana’s 2001-vintage Louisiana state net operating loss accumulated deferred income tax that results from the Vidalia tax deduction should be excluded from the 2005 test period bandwidth calculation. Various participants filed briefs on exceptions and/or briefs opposing exceptions related to the initial decision, including the LPSC, the APSC, the FERC trial staff, and Entergy Services. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6 These payments were made in July 2018. In January 2019 the FERC denied the LPSC’s request for rehearing of the May 2018 order. In May 2019 the FERC accepted the July 2018 compliance filing, and the LPSC sought rehearing of that decision in June 2019. Rough Production Cost Equalization 2010 Rate Filing Based on Calendar Year 2009 Production Costs In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010. Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests. In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund. After an abeyance of the proceeding schedule, a hearing was held in March 2014 and in December 2015 the FERC issued an order. Among other things, the December 2015 order directed Entergy to submit a compliance filing. In January 2016 the LPSC, the APSC, and Entergy filed requests for rehearing of the FERC’s December 2015 order. In February 2016, Entergy submitted the compliance filing ordered in the December 2015 order. The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3) In September 2016 the FERC accepted the February 2016 compliance filing subject to a further compliance filing made in November 2016. The further compliance filing was required as a result of an order issued in September 2016 ruling on the January 2016 rehearing requests filed by the LPSC, the APSC, and Entergy. In the order addressing the rehearing requests, the FERC granted the LPSC’s rehearing request and directed that interest be calculated on the payment/receipt amounts. The FERC also granted the APSC’s and Entergy’s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation. In November 2016, Entergy submitted its compliance filing in response to the FERC’s order on rehearing. The compliance filing included a revised calculation of the bandwidth true-up payments and receipts based on 2009 test year data and interest calculations. The LPSC protested the interest calculations. I n November 2017 the FERC issued an order rejecting the November 2016 compliance filing. The FERC determined that the payments detailed in the November 2016 compliance filing did not include adequate interest for the payments from Entergy Arkansas to Entergy Louisiana because it did not include interest on the principal portion of the payment that was made in February 2016. In December 2017, Entergy recalculated the interest pursuant to the November 2017 order. As a result of the recalculations, Entergy Arkansas owed very minor payments to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. In June 2019 the FERC issued an order denying the LPSC’s rehearing request of FERC’s September 2016 order. The LPSC rehearing request asked the FERC to reverse its decision that both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes should be removed from the bandwidth calculation. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action. In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period. The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring 30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding. Complaints Against System Energy Return on Equity and Capital Structure Complaints See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 27, 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019 settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding. In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24% . For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41% . In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint). In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period. In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the ne
Entergy Louisiana [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities 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. Regulatory activity regarding the Tax Cuts and Jobs Act System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and the hearing is scheduled for March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement are challenging the treatment and amount of excess tax liabilities associated with uncertain tax positions related to nuclear decommissioning. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020. Energy Cost Recovery Rider In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million , plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million , plus interest, as compared to the LPSC staff’s recommendation of $7.3 million , plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court. Entergy Texas In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million , including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending. 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 2019 Formula Rate Plan Filing In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018. The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million , which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted. These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing. In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the proposed formula rate plan rider revenue change to $14 million . Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million . The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a write off of the $11.2 million White Bluff scrubber regulatory asset. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing Commercial operation at St. Charles Power Station commenced in May 2019. 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 St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. 2018 Formula Rate Plan Filing In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million . While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million . This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues. Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing. Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests. Investigation of Costs Billed by Entergy Services In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit. Retail Rates - Gas 2018 Rate Stabilization Plan Filing As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. Gas Rate Stabilization Plan Extension Request In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13% , resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019. Filings with the City Council (Entergy New Orleans) Retail Rates See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case. That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ( $27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5% , but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ( $36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting. Filings with the PUCT (Entergy Texas) Base Rate Case In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million . The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions . In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million . In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT. Other Filings In March 2019, Entergy Texas filed with the PUCT a request to set a new distribution cost recovery factor (DCRF) rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application. In December 2018, Entergy Texas filed with the PUCT a request to set a new transmission cost recovery factor (TCRF) rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT. In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In the initial decision, the presiding judge agreed with the Utility operating companies’ position that: (1) interest on the bandwidth payments for the 2005 test period should be accrued from June 1, 2006 until the date that the bandwidth payments for that calculation are paid, which is consistent with how the Utility operating companies performed the calculation; and (2) a portion of Entergy Louisiana’s 2001-vintage Louisiana state net operating loss accumulated deferred income tax that results from the Vidalia tax deduction should be excluded from the 2005 test period bandwidth calculation. Various participants filed briefs on exceptions and/or briefs opposing exceptions related to the initial decision, including the LPSC, the APSC, the FERC trial staff, and Entergy Services. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6 These payments were made in July 2018. In January 2019 the FERC denied the LPSC’s request for rehearing of the May 2018 order. In May 2019 the FERC accepted the July 2018 compliance filing, and the LPSC sought rehearing of that decision in June 2019. Rough Production Cost Equalization 2010 Rate Filing Based on Calendar Year 2009 Production Costs In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010. Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests. In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund. After an abeyance of the proceeding schedule, a hearing was held in March 2014 and in December 2015 the FERC issued an order. Among other things, the December 2015 order directed Entergy to submit a compliance filing. In January 2016 the LPSC, the APSC, and Entergy filed requests for rehearing of the FERC’s December 2015 order. In February 2016, Entergy submitted the compliance filing ordered in the December 2015 order. The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3) In September 2016 the FERC accepted the February 2016 compliance filing subject to a further compliance filing made in November 2016. The further compliance filing was required as a result of an order issued in September 2016 ruling on the January 2016 rehearing requests filed by the LPSC, the APSC, and Entergy. In the order addressing the rehearing requests, the FERC granted the LPSC’s rehearing request and directed that interest be calculated on the payment/receipt amounts. The FERC also granted the APSC’s and Entergy’s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation. In November 2016, Entergy submitted its compliance filing in response to the FERC’s order on rehearing. The compliance filing included a revised calculation of the bandwidth true-up payments and receipts based on 2009 test year data and interest calculations. The LPSC protested the interest calculations. I n November 2017 the FERC issued an order rejecting the November 2016 compliance filing. The FERC determined that the payments detailed in the November 2016 compliance filing did not include adequate interest for the payments from Entergy Arkansas to Entergy Louisiana because it did not include interest on the principal portion of the payment that was made in February 2016. In December 2017, Entergy recalculated the interest pursuant to the November 2017 order. As a result of the recalculations, Entergy Arkansas owed very minor payments to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. In June 2019 the FERC issued an order denying the LPSC’s rehearing request of FERC’s September 2016 order. The LPSC rehearing request asked the FERC to reverse its decision that both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes should be removed from the bandwidth calculation. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action. In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period. The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring 30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding. Complaints Against System Energy Return on Equity and Capital Structure Complaints See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 27, 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019 settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding. In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24% . For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41% . In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint). In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period. In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the ne
Entergy Mississippi [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities 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. Regulatory activity regarding the Tax Cuts and Jobs Act System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and the hearing is scheduled for March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement are challenging the treatment and amount of excess tax liabilities associated with uncertain tax positions related to nuclear decommissioning. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020. Energy Cost Recovery Rider In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million , plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million , plus interest, as compared to the LPSC staff’s recommendation of $7.3 million , plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court. Entergy Texas In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million , including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending. 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 2019 Formula Rate Plan Filing In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018. The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million , which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted. These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing. In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the proposed formula rate plan rider revenue change to $14 million . Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million . The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a write off of the $11.2 million White Bluff scrubber regulatory asset. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing Commercial operation at St. Charles Power Station commenced in May 2019. 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 St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. 2018 Formula Rate Plan Filing In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million . While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million . This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues. Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing. Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests. Investigation of Costs Billed by Entergy Services In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit. Retail Rates - Gas 2018 Rate Stabilization Plan Filing As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. Gas Rate Stabilization Plan Extension Request In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13% , resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019. Filings with the City Council (Entergy New Orleans) Retail Rates See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case. That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ( $27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5% , but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ( $36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting. Filings with the PUCT (Entergy Texas) Base Rate Case In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million . The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions . In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million . In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT. Other Filings In March 2019, Entergy Texas filed with the PUCT a request to set a new distribution cost recovery factor (DCRF) rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application. In December 2018, Entergy Texas filed with the PUCT a request to set a new transmission cost recovery factor (TCRF) rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT. In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In the initial decision, the presiding judge agreed with the Utility operating companies’ position that: (1) interest on the bandwidth payments for the 2005 test period should be accrued from June 1, 2006 until the date that the bandwidth payments for that calculation are paid, which is consistent with how the Utility operating companies performed the calculation; and (2) a portion of Entergy Louisiana’s 2001-vintage Louisiana state net operating loss accumulated deferred income tax that results from the Vidalia tax deduction should be excluded from the 2005 test period bandwidth calculation. Various participants filed briefs on exceptions and/or briefs opposing exceptions related to the initial decision, including the LPSC, the APSC, the FERC trial staff, and Entergy Services. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6 These payments were made in July 2018. In January 2019 the FERC denied the LPSC’s request for rehearing of the May 2018 order. In May 2019 the FERC accepted the July 2018 compliance filing, and the LPSC sought rehearing of that decision in June 2019. Rough Production Cost Equalization 2010 Rate Filing Based on Calendar Year 2009 Production Costs In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010. Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests. In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund. After an abeyance of the proceeding schedule, a hearing was held in March 2014 and in December 2015 the FERC issued an order. Among other things, the December 2015 order directed Entergy to submit a compliance filing. In January 2016 the LPSC, the APSC, and Entergy filed requests for rehearing of the FERC’s December 2015 order. In February 2016, Entergy submitted the compliance filing ordered in the December 2015 order. The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3) In September 2016 the FERC accepted the February 2016 compliance filing subject to a further compliance filing made in November 2016. The further compliance filing was required as a result of an order issued in September 2016 ruling on the January 2016 rehearing requests filed by the LPSC, the APSC, and Entergy. In the order addressing the rehearing requests, the FERC granted the LPSC’s rehearing request and directed that interest be calculated on the payment/receipt amounts. The FERC also granted the APSC’s and Entergy’s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation. In November 2016, Entergy submitted its compliance filing in response to the FERC’s order on rehearing. The compliance filing included a revised calculation of the bandwidth true-up payments and receipts based on 2009 test year data and interest calculations. The LPSC protested the interest calculations. I n November 2017 the FERC issued an order rejecting the November 2016 compliance filing. The FERC determined that the payments detailed in the November 2016 compliance filing did not include adequate interest for the payments from Entergy Arkansas to Entergy Louisiana because it did not include interest on the principal portion of the payment that was made in February 2016. In December 2017, Entergy recalculated the interest pursuant to the November 2017 order. As a result of the recalculations, Entergy Arkansas owed very minor payments to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. In June 2019 the FERC issued an order denying the LPSC’s rehearing request of FERC’s September 2016 order. The LPSC rehearing request asked the FERC to reverse its decision that both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes should be removed from the bandwidth calculation. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action. In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period. The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring 30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding. Complaints Against System Energy Return on Equity and Capital Structure Complaints See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 27, 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019 settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding. In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24% . For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41% . In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint). In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period. In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the ne
Entergy New Orleans [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities 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. Regulatory activity regarding the Tax Cuts and Jobs Act System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and the hearing is scheduled for March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement are challenging the treatment and amount of excess tax liabilities associated with uncertain tax positions related to nuclear decommissioning. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020. Energy Cost Recovery Rider In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million , plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million , plus interest, as compared to the LPSC staff’s recommendation of $7.3 million , plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court. Entergy Texas In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million , including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending. 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 2019 Formula Rate Plan Filing In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018. The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million , which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted. These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing. In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the proposed formula rate plan rider revenue change to $14 million . Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million . The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a write off of the $11.2 million White Bluff scrubber regulatory asset. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing Commercial operation at St. Charles Power Station commenced in May 2019. 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 St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. 2018 Formula Rate Plan Filing In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million . While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million . This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues. Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing. Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests. Investigation of Costs Billed by Entergy Services In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit. Retail Rates - Gas 2018 Rate Stabilization Plan Filing As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. Gas Rate Stabilization Plan Extension Request In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13% , resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019. Filings with the City Council (Entergy New Orleans) Retail Rates See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case. That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ( $27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5% , but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ( $36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting. Filings with the PUCT (Entergy Texas) Base Rate Case In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million . The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions . In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million . In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT. Other Filings In March 2019, Entergy Texas filed with the PUCT a request to set a new distribution cost recovery factor (DCRF) rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application. In December 2018, Entergy Texas filed with the PUCT a request to set a new transmission cost recovery factor (TCRF) rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT. In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In the initial decision, the presiding judge agreed with the Utility operating companies’ position that: (1) interest on the bandwidth payments for the 2005 test period should be accrued from June 1, 2006 until the date that the bandwidth payments for that calculation are paid, which is consistent with how the Utility operating companies performed the calculation; and (2) a portion of Entergy Louisiana’s 2001-vintage Louisiana state net operating loss accumulated deferred income tax that results from the Vidalia tax deduction should be excluded from the 2005 test period bandwidth calculation. Various participants filed briefs on exceptions and/or briefs opposing exceptions related to the initial decision, including the LPSC, the APSC, the FERC trial staff, and Entergy Services. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6 These payments were made in July 2018. In January 2019 the FERC denied the LPSC’s request for rehearing of the May 2018 order. In May 2019 the FERC accepted the July 2018 compliance filing, and the LPSC sought rehearing of that decision in June 2019. Rough Production Cost Equalization 2010 Rate Filing Based on Calendar Year 2009 Production Costs In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010. Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests. In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund. After an abeyance of the proceeding schedule, a hearing was held in March 2014 and in December 2015 the FERC issued an order. Among other things, the December 2015 order directed Entergy to submit a compliance filing. In January 2016 the LPSC, the APSC, and Entergy filed requests for rehearing of the FERC’s December 2015 order. In February 2016, Entergy submitted the compliance filing ordered in the December 2015 order. The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3) In September 2016 the FERC accepted the February 2016 compliance filing subject to a further compliance filing made in November 2016. The further compliance filing was required as a result of an order issued in September 2016 ruling on the January 2016 rehearing requests filed by the LPSC, the APSC, and Entergy. In the order addressing the rehearing requests, the FERC granted the LPSC’s rehearing request and directed that interest be calculated on the payment/receipt amounts. The FERC also granted the APSC’s and Entergy’s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation. In November 2016, Entergy submitted its compliance filing in response to the FERC’s order on rehearing. The compliance filing included a revised calculation of the bandwidth true-up payments and receipts based on 2009 test year data and interest calculations. The LPSC protested the interest calculations. I n November 2017 the FERC issued an order rejecting the November 2016 compliance filing. The FERC determined that the payments detailed in the November 2016 compliance filing did not include adequate interest for the payments from Entergy Arkansas to Entergy Louisiana because it did not include interest on the principal portion of the payment that was made in February 2016. In December 2017, Entergy recalculated the interest pursuant to the November 2017 order. As a result of the recalculations, Entergy Arkansas owed very minor payments to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. In June 2019 the FERC issued an order denying the LPSC’s rehearing request of FERC’s September 2016 order. The LPSC rehearing request asked the FERC to reverse its decision that both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes should be removed from the bandwidth calculation. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action. In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period. The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring 30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding. Complaints Against System Energy Return on Equity and Capital Structure Complaints See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 27, 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019 settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding. In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24% . For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41% . In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint). In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period. In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the ne
Entergy Texas [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities 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. Regulatory activity regarding the Tax Cuts and Jobs Act System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and the hearing is scheduled for March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement are challenging the treatment and amount of excess tax liabilities associated with uncertain tax positions related to nuclear decommissioning. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020. Energy Cost Recovery Rider In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million , plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million , plus interest, as compared to the LPSC staff’s recommendation of $7.3 million , plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court. Entergy Texas In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million , including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending. 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 2019 Formula Rate Plan Filing In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018. The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million , which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted. These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing. In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the proposed formula rate plan rider revenue change to $14 million . Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million . The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a write off of the $11.2 million White Bluff scrubber regulatory asset. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing Commercial operation at St. Charles Power Station commenced in May 2019. 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 St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. 2018 Formula Rate Plan Filing In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million . While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million . This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues. Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing. Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests. Investigation of Costs Billed by Entergy Services In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit. Retail Rates - Gas 2018 Rate Stabilization Plan Filing As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. Gas Rate Stabilization Plan Extension Request In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13% , resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019. Filings with the City Council (Entergy New Orleans) Retail Rates See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case. That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ( $27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5% , but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ( $36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting. Filings with the PUCT (Entergy Texas) Base Rate Case In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million . The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions . In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million . In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT. Other Filings In March 2019, Entergy Texas filed with the PUCT a request to set a new distribution cost recovery factor (DCRF) rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application. In December 2018, Entergy Texas filed with the PUCT a request to set a new transmission cost recovery factor (TCRF) rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT. In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In the initial decision, the presiding judge agreed with the Utility operating companies’ position that: (1) interest on the bandwidth payments for the 2005 test period should be accrued from June 1, 2006 until the date that the bandwidth payments for that calculation are paid, which is consistent with how the Utility operating companies performed the calculation; and (2) a portion of Entergy Louisiana’s 2001-vintage Louisiana state net operating loss accumulated deferred income tax that results from the Vidalia tax deduction should be excluded from the 2005 test period bandwidth calculation. Various participants filed briefs on exceptions and/or briefs opposing exceptions related to the initial decision, including the LPSC, the APSC, the FERC trial staff, and Entergy Services. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6 These payments were made in July 2018. In January 2019 the FERC denied the LPSC’s request for rehearing of the May 2018 order. In May 2019 the FERC accepted the July 2018 compliance filing, and the LPSC sought rehearing of that decision in June 2019. Rough Production Cost Equalization 2010 Rate Filing Based on Calendar Year 2009 Production Costs In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010. Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests. In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund. After an abeyance of the proceeding schedule, a hearing was held in March 2014 and in December 2015 the FERC issued an order. Among other things, the December 2015 order directed Entergy to submit a compliance filing. In January 2016 the LPSC, the APSC, and Entergy filed requests for rehearing of the FERC’s December 2015 order. In February 2016, Entergy submitted the compliance filing ordered in the December 2015 order. The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3) In September 2016 the FERC accepted the February 2016 compliance filing subject to a further compliance filing made in November 2016. The further compliance filing was required as a result of an order issued in September 2016 ruling on the January 2016 rehearing requests filed by the LPSC, the APSC, and Entergy. In the order addressing the rehearing requests, the FERC granted the LPSC’s rehearing request and directed that interest be calculated on the payment/receipt amounts. The FERC also granted the APSC’s and Entergy’s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation. In November 2016, Entergy submitted its compliance filing in response to the FERC’s order on rehearing. The compliance filing included a revised calculation of the bandwidth true-up payments and receipts based on 2009 test year data and interest calculations. The LPSC protested the interest calculations. I n November 2017 the FERC issued an order rejecting the November 2016 compliance filing. The FERC determined that the payments detailed in the November 2016 compliance filing did not include adequate interest for the payments from Entergy Arkansas to Entergy Louisiana because it did not include interest on the principal portion of the payment that was made in February 2016. In December 2017, Entergy recalculated the interest pursuant to the November 2017 order. As a result of the recalculations, Entergy Arkansas owed very minor payments to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. In June 2019 the FERC issued an order denying the LPSC’s rehearing request of FERC’s September 2016 order. The LPSC rehearing request asked the FERC to reverse its decision that both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes should be removed from the bandwidth calculation. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action. In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period. The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring 30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding. Complaints Against System Energy Return on Equity and Capital Structure Complaints See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 27, 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019 settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding. In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24% . For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41% . In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint). In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period. In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the ne
System Energy [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities 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. Regulatory activity regarding the Tax Cuts and Jobs Act System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and the hearing is scheduled for March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement are challenging the treatment and amount of excess tax liabilities associated with uncertain tax positions related to nuclear decommissioning. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020. Energy Cost Recovery Rider In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million , plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million , plus interest, as compared to the LPSC staff’s recommendation of $7.3 million , plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court. Entergy Texas In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million , including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending. 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 2019 Formula Rate Plan Filing In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018. The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million , which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted. These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing. In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the proposed formula rate plan rider revenue change to $14 million . Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million . The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a write off of the $11.2 million White Bluff scrubber regulatory asset. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing Commercial operation at St. Charles Power Station commenced in May 2019. 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 St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. 2018 Formula Rate Plan Filing In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million . While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million . This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues. Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing. Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests. Investigation of Costs Billed by Entergy Services In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit. Retail Rates - Gas 2018 Rate Stabilization Plan Filing As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. Gas Rate Stabilization Plan Extension Request In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13% , resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019. Filings with the City Council (Entergy New Orleans) Retail Rates See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case. That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ( $27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5% , but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ( $36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting. Filings with the PUCT (Entergy Texas) Base Rate Case In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million . The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions . In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million . In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT. Other Filings In March 2019, Entergy Texas filed with the PUCT a request to set a new distribution cost recovery factor (DCRF) rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application. In December 2018, Entergy Texas filed with the PUCT a request to set a new transmission cost recovery factor (TCRF) rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT. In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In the initial decision, the presiding judge agreed with the Utility operating companies’ position that: (1) interest on the bandwidth payments for the 2005 test period should be accrued from June 1, 2006 until the date that the bandwidth payments for that calculation are paid, which is consistent with how the Utility operating companies performed the calculation; and (2) a portion of Entergy Louisiana’s 2001-vintage Louisiana state net operating loss accumulated deferred income tax that results from the Vidalia tax deduction should be excluded from the 2005 test period bandwidth calculation. Various participants filed briefs on exceptions and/or briefs opposing exceptions related to the initial decision, including the LPSC, the APSC, the FERC trial staff, and Entergy Services. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6 These payments were made in July 2018. In January 2019 the FERC denied the LPSC’s request for rehearing of the May 2018 order. In May 2019 the FERC accepted the July 2018 compliance filing, and the LPSC sought rehearing of that decision in June 2019. Rough Production Cost Equalization 2010 Rate Filing Based on Calendar Year 2009 Production Costs In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010. Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests. In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund. After an abeyance of the proceeding schedule, a hearing was held in March 2014 and in December 2015 the FERC issued an order. Among other things, the December 2015 order directed Entergy to submit a compliance filing. In January 2016 the LPSC, the APSC, and Entergy filed requests for rehearing of the FERC’s December 2015 order. In February 2016, Entergy submitted the compliance filing ordered in the December 2015 order. The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3) In September 2016 the FERC accepted the February 2016 compliance filing subject to a further compliance filing made in November 2016. The further compliance filing was required as a result of an order issued in September 2016 ruling on the January 2016 rehearing requests filed by the LPSC, the APSC, and Entergy. In the order addressing the rehearing requests, the FERC granted the LPSC’s rehearing request and directed that interest be calculated on the payment/receipt amounts. The FERC also granted the APSC’s and Entergy’s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation. In November 2016, Entergy submitted its compliance filing in response to the FERC’s order on rehearing. The compliance filing included a revised calculation of the bandwidth true-up payments and receipts based on 2009 test year data and interest calculations. The LPSC protested the interest calculations. I n November 2017 the FERC issued an order rejecting the November 2016 compliance filing. The FERC determined that the payments detailed in the November 2016 compliance filing did not include adequate interest for the payments from Entergy Arkansas to Entergy Louisiana because it did not include interest on the principal portion of the payment that was made in February 2016. In December 2017, Entergy recalculated the interest pursuant to the November 2017 order. As a result of the recalculations, Entergy Arkansas owed very minor payments to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. In June 2019 the FERC issued an order denying the LPSC’s rehearing request of FERC’s September 2016 order. The LPSC rehearing request asked the FERC to reverse its decision that both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes should be removed from the bandwidth calculation. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action. In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period. The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring 30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding. Complaints Against System Energy Return on Equity and Capital Structure Complaints See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 27, 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019 settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding. In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24% . For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41% . In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint). In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period. In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the ne

Equity

Equity	9 Months Ended
	Sep. 30, 2019
Equity	EQUITY (Entergy Corporation, Entergy Louisiana, and Entergy Texas) Common Stock Earnings 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 September 30, 2019 2018 (In Millions, Except Per Share Data) Income Shares $/share Income Shares $/share Basic earnings per share Net income attributable to Entergy Corporation $365.2 198.9 $1.84 $536.4 181.0 $2.96 Average dilutive effect of: Stock options 0.7 (0.01 ) 0.4 (0.01 ) Other equity plans 0.9 (0.01 ) 0.8 (0.01 ) Equity forwards — — 1.5 (0.02 ) Diluted earnings per share $365.2 200.5 $1.82 $536.4 183.7 $2.92 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.1 million for the three months ended September 30, 2018 . For the Nine Months Ended September 30, 2019 2018 (In Millions, Except Per Share Data) Income Shares $/share Income Shares $/share Basic earnings per share Net income attributable to Entergy Corporation $856.2 193.9 $4.42 $914.6 180.8 $5.06 Average dilutive effect of: Stock options 0.5 (0.01 ) 0.3 (0.01 ) Other equity plans 0.7 (0.02 ) 0.7 (0.01 ) Equity forwards 0.6 (0.01 ) 0.9 (0.03 ) Diluted earnings per share $856.2 195.7 $4.38 $914.6 182.7 $5.01 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.2 million for the nine months ended September 30, 2019 and approximately 1.1 million for the nine months ended September 30, 2018 . 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 $0.91 for the three months ended September 30, 2019 and $0.89 for the three months ended September 30, 2018 . Dividends declared per common share were $2.73 for the nine months ended September 30, 2019 and $2.67 for the nine months ended September 30, 2018 . Equity Forward Sale Agreements As discussed in Note 7 to the financial statements in the Form 10-K, in June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. In December 2018, Entergy physically settled a portion of its obligations under the forward sale agreements by delivering 6,834,221 shares of common stock in exchange for cash proceeds of approximately $500 million . In May 2019, Entergy physically settled the remaining 8,448,171 shares of common stock in exchange for cash proceeds of approximately $608 million . Treasury Stock During the nine months ended September 30, 2019 , Entergy Corporation issued 1,582,916 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 nine months ended September 30, 2019 . Retained Earnings On October 25, 2019, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.93 per share, payable on December 2, 2019, to holders of record as of November 7, 2019. Entergy implemented ASU No. 2017-12 “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities” effective January 1, 2019. The ASU makes a number of amendments to hedge accounting, most significantly changing the recognition and presentation of highly effective hedges. Entergy implemented this standard using a modified retrospective method, and recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by approximately $8 million as of January 1, 2019 for the cumulative effect of the ineffectiveness portion of designated hedges on nuclear power sales. Entergy implemented ASU 2017-08 “Receivables (Topic 310): Nonrefundable Fees and Other Costs” effective January 1, 2019. The ASU amends the amortization period for certain purchased callable debt securities held at a premium to the earliest call date. Entergy implemented this standard using the modified retrospective approach, and recorded an adjustment decreasing retained earnings and decreasing accumulated other comprehensive loss by approximately $1 million as of January 1, 2019 for the cumulative effect of the amended amortization period. 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 September 30, 2019 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, July 1, 2019 $51,736 ($508,876 ) $26,736 ($430,404 ) Other comprehensive income (loss) before reclassifications (5,190 ) — 8,350 3,160 Amounts reclassified from accumulated other comprehensive income (loss) (14,913 ) 25,464 (3,079 ) 7,472 Net other comprehensive income (loss) for the period (20,103 ) 25,464 5,271 10,632 Ending balance, September 30, 2019 $31,633 ($483,412 ) $32,007 ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, July 1, 2018 ($14,874 ) ($589,926 ) ($8,842 ) ($613,642 ) Other comprehensive income (loss) before reclassifications (40,401 ) — (7,173 ) (47,574 ) Amounts reclassified from accumulated other comprehensive income (loss) 8,397 15,265 5,428 29,090 Net other comprehensive income (loss) for the period (32,004 ) 15,265 (1,745 ) (18,484 ) Ending balance, September 30, 2018 ($46,878 ) ($574,661 ) ($10,587 ) ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2019 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Ending balance, December 31, 2018 ($23,135 ) ($531,922 ) ($2,116 ) ($557,173 ) Implementation of accounting standards (7,685 ) — 879 (6,806 ) Beginning balance, January 1, 2019 ($30,820 ) ($531,922 ) ($1,237 ) ($563,979 ) Other comprehensive income (loss) before reclassifications 122,481 — 37,724 160,205 Amounts reclassified from accumulated other comprehensive income (loss) (60,028 ) 48,510 (4,480 ) (15,998 ) Net other comprehensive income (loss) for the period 62,453 48,510 33,244 144,207 Ending balance, September 30, 2019 $31,633 ($483,412 ) $32,007 ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Ending balance, December 31, 2017 ($37,477 ) ($531,099 ) $545,045 ($23,531 ) Implementation of accounting standards — — (632,617 ) (632,617 ) Beginning balance, January 1, 2018 ($37,477 ) ($531,099 ) ($87,572 ) ($656,148 ) Other comprehensive income (loss) before reclassifications (31,816 ) — (50,958 ) (82,774 ) Amounts reclassified from accumulated other comprehensive income (loss) 30,171 47,404 13,716 91,291 Net other comprehensive income (loss) for the period (1,645 ) 47,404 (37,242 ) 8,517 Reclassification pursuant to ASU 2018-02 (7,756 ) (90,966 ) 114,227 15,505 Ending balance, September 30, 2018 ($46,878 ) ($574,661 ) ($10,587 ) ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2019 and 2018: Pension and Other 2019 2018 (In Thousands) Beginning balance, July 1, ($8,091 ) ($57,451 ) Amounts reclassified from accumulated other (969 ) (500 ) Net other comprehensive income (loss) for the period (969 ) (500 ) Ending balance, September 30, ($9,060 ) ($57,951 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2019 and 2018: Pension and Other 2019 2018 (In Thousands) Beginning balance, January 1, ($6,153 ) ($46,400 ) Amounts reclassified from accumulated other (2,907 ) (1,502 ) Net other comprehensive income (loss) for the period (2,907 ) (1,502 ) Reclassification pursuant to ASU 2018-02 — (10,049 ) Ending balance, September 30, ($9,060 ) ($57,951 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended September 30, 2019 and 2018 are as follows: Amounts reclassified Income Statement Location 2019 2018 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $18,925 ($10,566 ) Competitive business operating revenues Interest rate swaps (48 ) (63 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 18,877 (10,629 ) (3,964 ) 2,232 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $14,913 ($8,397 ) Pension and other postretirement liabilities Amortization of prior-service credit $5,325 $5,425 (a) Amortization of loss (20,919 ) (24,740 ) (a) Settlement loss (16,630 ) (76 ) (a) Total amortization (32,224 ) (19,391 ) 6,760 4,126 Income taxes Total amortization (net of tax) ($25,464 ) ($15,265 ) Net unrealized investment gain (loss) Realized gain (loss) $4,872 ($8,589 ) Interest and investment income (1,793 ) 3,161 Income taxes Total realized investment gain (loss) (net of tax) $3,079 ($5,428 ) Total reclassifications for the period (net of tax) ($7,472 ) ($29,090 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the nine months ended September 30, 2019 and 2018 are as follows: Amounts reclassified from AOCI Income Statement Location 2019 2018 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $76,129 ($37,913 ) Competitive business operating revenues Interest rate swaps (145 ) (278 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 75,984 (38,191 ) (15,956 ) 8,020 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $60,028 ($30,171 ) Pension and other postretirement liabilities Amortization of prior-service credit $15,977 $16,278 (a) Amortization of loss (58,888 ) (74,503 ) (a) Settlement loss (18,685 ) (2,098 ) (a) Total amortization (61,596 ) (60,323 ) 13,086 12,919 Income taxes Total amortization (net of tax) ($48,510 ) ($47,404 ) Net unrealized investment gain (loss) Realized gain (loss) $7,088 ($21,703 ) Interest and investment income (2,608 ) 7,987 Income taxes Total realized investment gain (loss) (net of tax) $4,480 ($13,716 ) Total reclassifications for the period (net of tax) $15,998 ($91,291 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended September 30, 2019 and 2018 are as follows: Amounts reclassified Income Statement Location 2019 2018 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,837 $1,934 (a) Amortization of loss (526 ) (1,257 ) (a) Total amortization 1,311 677 (342 ) (177 ) Income taxes Total amortization (net of tax) 969 500 Total reclassifications for the period (net of tax) $969 $500 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the nine months ended September 30, 2019 and 2018 are as follows: Amounts reclassified Income Statement Location 2019 2018 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,511 $5,802 (a) Amortization of loss (1,578 ) (3,770 ) (a) Total amortization 3,933 2,032 (1,026 ) (530 ) Income taxes Total amortization (net of tax) 2,907 1,502 Total reclassifications for the period (net of tax) $2,907 $1,502 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Preferred Stock In September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of September 30, 2019. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share. Accounting standards regarding the classification and measurement of redeemable securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem their securities, even if the likelihood of occurrence of these circumstances is considered remote. The outstanding preferred stock of Entergy Texas has protective rights with respect to unpaid dividends but provides for the election of board members that would not constitute a majority of the board, and the preferred stock of Entergy Texas is therefore classified as a component of equity.
Entergy Texas [Member]
Equity	EQUITY (Entergy Corporation, Entergy Louisiana, and Entergy Texas) Common Stock Earnings 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 September 30, 2019 2018 (In Millions, Except Per Share Data) Income Shares $/share Income Shares $/share Basic earnings per share Net income attributable to Entergy Corporation $365.2 198.9 $1.84 $536.4 181.0 $2.96 Average dilutive effect of: Stock options 0.7 (0.01 ) 0.4 (0.01 ) Other equity plans 0.9 (0.01 ) 0.8 (0.01 ) Equity forwards — — 1.5 (0.02 ) Diluted earnings per share $365.2 200.5 $1.82 $536.4 183.7 $2.92 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.1 million for the three months ended September 30, 2018 . For the Nine Months Ended September 30, 2019 2018 (In Millions, Except Per Share Data) Income Shares $/share Income Shares $/share Basic earnings per share Net income attributable to Entergy Corporation $856.2 193.9 $4.42 $914.6 180.8 $5.06 Average dilutive effect of: Stock options 0.5 (0.01 ) 0.3 (0.01 ) Other equity plans 0.7 (0.02 ) 0.7 (0.01 ) Equity forwards 0.6 (0.01 ) 0.9 (0.03 ) Diluted earnings per share $856.2 195.7 $4.38 $914.6 182.7 $5.01 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.2 million for the nine months ended September 30, 2019 and approximately 1.1 million for the nine months ended September 30, 2018 . 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 $0.91 for the three months ended September 30, 2019 and $0.89 for the three months ended September 30, 2018 . Dividends declared per common share were $2.73 for the nine months ended September 30, 2019 and $2.67 for the nine months ended September 30, 2018 . Equity Forward Sale Agreements As discussed in Note 7 to the financial statements in the Form 10-K, in June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. In December 2018, Entergy physically settled a portion of its obligations under the forward sale agreements by delivering 6,834,221 shares of common stock in exchange for cash proceeds of approximately $500 million . In May 2019, Entergy physically settled the remaining 8,448,171 shares of common stock in exchange for cash proceeds of approximately $608 million . Treasury Stock During the nine months ended September 30, 2019 , Entergy Corporation issued 1,582,916 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 nine months ended September 30, 2019 . Retained Earnings On October 25, 2019, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.93 per share, payable on December 2, 2019, to holders of record as of November 7, 2019. Entergy implemented ASU No. 2017-12 “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities” effective January 1, 2019. The ASU makes a number of amendments to hedge accounting, most significantly changing the recognition and presentation of highly effective hedges. Entergy implemented this standard using a modified retrospective method, and recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by approximately $8 million as of January 1, 2019 for the cumulative effect of the ineffectiveness portion of designated hedges on nuclear power sales. Entergy implemented ASU 2017-08 “Receivables (Topic 310): Nonrefundable Fees and Other Costs” effective January 1, 2019. The ASU amends the amortization period for certain purchased callable debt securities held at a premium to the earliest call date. Entergy implemented this standard using the modified retrospective approach, and recorded an adjustment decreasing retained earnings and decreasing accumulated other comprehensive loss by approximately $1 million as of January 1, 2019 for the cumulative effect of the amended amortization period. 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 September 30, 2019 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, July 1, 2019 $51,736 ($508,876 ) $26,736 ($430,404 ) Other comprehensive income (loss) before reclassifications (5,190 ) — 8,350 3,160 Amounts reclassified from accumulated other comprehensive income (loss) (14,913 ) 25,464 (3,079 ) 7,472 Net other comprehensive income (loss) for the period (20,103 ) 25,464 5,271 10,632 Ending balance, September 30, 2019 $31,633 ($483,412 ) $32,007 ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, July 1, 2018 ($14,874 ) ($589,926 ) ($8,842 ) ($613,642 ) Other comprehensive income (loss) before reclassifications (40,401 ) — (7,173 ) (47,574 ) Amounts reclassified from accumulated other comprehensive income (loss) 8,397 15,265 5,428 29,090 Net other comprehensive income (loss) for the period (32,004 ) 15,265 (1,745 ) (18,484 ) Ending balance, September 30, 2018 ($46,878 ) ($574,661 ) ($10,587 ) ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2019 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Ending balance, December 31, 2018 ($23,135 ) ($531,922 ) ($2,116 ) ($557,173 ) Implementation of accounting standards (7,685 ) — 879 (6,806 ) Beginning balance, January 1, 2019 ($30,820 ) ($531,922 ) ($1,237 ) ($563,979 ) Other comprehensive income (loss) before reclassifications 122,481 — 37,724 160,205 Amounts reclassified from accumulated other comprehensive income (loss) (60,028 ) 48,510 (4,480 ) (15,998 ) Net other comprehensive income (loss) for the period 62,453 48,510 33,244 144,207 Ending balance, September 30, 2019 $31,633 ($483,412 ) $32,007 ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Ending balance, December 31, 2017 ($37,477 ) ($531,099 ) $545,045 ($23,531 ) Implementation of accounting standards — — (632,617 ) (632,617 ) Beginning balance, January 1, 2018 ($37,477 ) ($531,099 ) ($87,572 ) ($656,148 ) Other comprehensive income (loss) before reclassifications (31,816 ) — (50,958 ) (82,774 ) Amounts reclassified from accumulated other comprehensive income (loss) 30,171 47,404 13,716 91,291 Net other comprehensive income (loss) for the period (1,645 ) 47,404 (37,242 ) 8,517 Reclassification pursuant to ASU 2018-02 (7,756 ) (90,966 ) 114,227 15,505 Ending balance, September 30, 2018 ($46,878 ) ($574,661 ) ($10,587 ) ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2019 and 2018: Pension and Other 2019 2018 (In Thousands) Beginning balance, July 1, ($8,091 ) ($57,451 ) Amounts reclassified from accumulated other (969 ) (500 ) Net other comprehensive income (loss) for the period (969 ) (500 ) Ending balance, September 30, ($9,060 ) ($57,951 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2019 and 2018: Pension and Other 2019 2018 (In Thousands) Beginning balance, January 1, ($6,153 ) ($46,400 ) Amounts reclassified from accumulated other (2,907 ) (1,502 ) Net other comprehensive income (loss) for the period (2,907 ) (1,502 ) Reclassification pursuant to ASU 2018-02 — (10,049 ) Ending balance, September 30, ($9,060 ) ($57,951 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended September 30, 2019 and 2018 are as follows: Amounts reclassified Income Statement Location 2019 2018 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $18,925 ($10,566 ) Competitive business operating revenues Interest rate swaps (48 ) (63 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 18,877 (10,629 ) (3,964 ) 2,232 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $14,913 ($8,397 ) Pension and other postretirement liabilities Amortization of prior-service credit $5,325 $5,425 (a) Amortization of loss (20,919 ) (24,740 ) (a) Settlement loss (16,630 ) (76 ) (a) Total amortization (32,224 ) (19,391 ) 6,760 4,126 Income taxes Total amortization (net of tax) ($25,464 ) ($15,265 ) Net unrealized investment gain (loss) Realized gain (loss) $4,872 ($8,589 ) Interest and investment income (1,793 ) 3,161 Income taxes Total realized investment gain (loss) (net of tax) $3,079 ($5,428 ) Total reclassifications for the period (net of tax) ($7,472 ) ($29,090 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the nine months ended September 30, 2019 and 2018 are as follows: Amounts reclassified from AOCI Income Statement Location 2019 2018 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $76,129 ($37,913 ) Competitive business operating revenues Interest rate swaps (145 ) (278 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 75,984 (38,191 ) (15,956 ) 8,020 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $60,028 ($30,171 ) Pension and other postretirement liabilities Amortization of prior-service credit $15,977 $16,278 (a) Amortization of loss (58,888 ) (74,503 ) (a) Settlement loss (18,685 ) (2,098 ) (a) Total amortization (61,596 ) (60,323 ) 13,086 12,919 Income taxes Total amortization (net of tax) ($48,510 ) ($47,404 ) Net unrealized investment gain (loss) Realized gain (loss) $7,088 ($21,703 ) Interest and investment income (2,608 ) 7,987 Income taxes Total realized investment gain (loss) (net of tax) $4,480 ($13,716 ) Total reclassifications for the period (net of tax) $15,998 ($91,291 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended September 30, 2019 and 2018 are as follows: Amounts reclassified Income Statement Location 2019 2018 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,837 $1,934 (a) Amortization of loss (526 ) (1,257 ) (a) Total amortization 1,311 677 (342 ) (177 ) Income taxes Total amortization (net of tax) 969 500 Total reclassifications for the period (net of tax) $969 $500 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the nine months ended September 30, 2019 and 2018 are as follows: Amounts reclassified Income Statement Location 2019 2018 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,511 $5,802 (a) Amortization of loss (1,578 ) (3,770 ) (a) Total amortization 3,933 2,032 (1,026 ) (530 ) Income taxes Total amortization (net of tax) 2,907 1,502 Total reclassifications for the period (net of tax) $2,907 $1,502 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Preferred Stock In September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of September 30, 2019. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share. Accounting standards regarding the classification and measurement of redeemable securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem their securities, even if the likelihood of occurrence of these circumstances is considered remote. The outstanding preferred stock of Entergy Texas has protective rights with respect to unpaid dividends but provides for the election of board members that would not constitute a majority of the board, and the preferred stock of Entergy Texas is therefore classified as a component of equity.
Entergy Louisiana [Member]
Equity	EQUITY (Entergy Corporation, Entergy Louisiana, and Entergy Texas) Common Stock Earnings 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 September 30, 2019 2018 (In Millions, Except Per Share Data) Income Shares $/share Income Shares $/share Basic earnings per share Net income attributable to Entergy Corporation $365.2 198.9 $1.84 $536.4 181.0 $2.96 Average dilutive effect of: Stock options 0.7 (0.01 ) 0.4 (0.01 ) Other equity plans 0.9 (0.01 ) 0.8 (0.01 ) Equity forwards — — 1.5 (0.02 ) Diluted earnings per share $365.2 200.5 $1.82 $536.4 183.7 $2.92 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.1 million for the three months ended September 30, 2018 . For the Nine Months Ended September 30, 2019 2018 (In Millions, Except Per Share Data) Income Shares $/share Income Shares $/share Basic earnings per share Net income attributable to Entergy Corporation $856.2 193.9 $4.42 $914.6 180.8 $5.06 Average dilutive effect of: Stock options 0.5 (0.01 ) 0.3 (0.01 ) Other equity plans 0.7 (0.02 ) 0.7 (0.01 ) Equity forwards 0.6 (0.01 ) 0.9 (0.03 ) Diluted earnings per share $856.2 195.7 $4.38 $914.6 182.7 $5.01 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.2 million for the nine months ended September 30, 2019 and approximately 1.1 million for the nine months ended September 30, 2018 . 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 $0.91 for the three months ended September 30, 2019 and $0.89 for the three months ended September 30, 2018 . Dividends declared per common share were $2.73 for the nine months ended September 30, 2019 and $2.67 for the nine months ended September 30, 2018 . Equity Forward Sale Agreements As discussed in Note 7 to the financial statements in the Form 10-K, in June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. In December 2018, Entergy physically settled a portion of its obligations under the forward sale agreements by delivering 6,834,221 shares of common stock in exchange for cash proceeds of approximately $500 million . In May 2019, Entergy physically settled the remaining 8,448,171 shares of common stock in exchange for cash proceeds of approximately $608 million . Treasury Stock During the nine months ended September 30, 2019 , Entergy Corporation issued 1,582,916 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 nine months ended September 30, 2019 . Retained Earnings On October 25, 2019, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.93 per share, payable on December 2, 2019, to holders of record as of November 7, 2019. Entergy implemented ASU No. 2017-12 “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities” effective January 1, 2019. The ASU makes a number of amendments to hedge accounting, most significantly changing the recognition and presentation of highly effective hedges. Entergy implemented this standard using a modified retrospective method, and recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by approximately $8 million as of January 1, 2019 for the cumulative effect of the ineffectiveness portion of designated hedges on nuclear power sales. Entergy implemented ASU 2017-08 “Receivables (Topic 310): Nonrefundable Fees and Other Costs” effective January 1, 2019. The ASU amends the amortization period for certain purchased callable debt securities held at a premium to the earliest call date. Entergy implemented this standard using the modified retrospective approach, and recorded an adjustment decreasing retained earnings and decreasing accumulated other comprehensive loss by approximately $1 million as of January 1, 2019 for the cumulative effect of the amended amortization period. 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 September 30, 2019 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, July 1, 2019 $51,736 ($508,876 ) $26,736 ($430,404 ) Other comprehensive income (loss) before reclassifications (5,190 ) — 8,350 3,160 Amounts reclassified from accumulated other comprehensive income (loss) (14,913 ) 25,464 (3,079 ) 7,472 Net other comprehensive income (loss) for the period (20,103 ) 25,464 5,271 10,632 Ending balance, September 30, 2019 $31,633 ($483,412 ) $32,007 ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, July 1, 2018 ($14,874 ) ($589,926 ) ($8,842 ) ($613,642 ) Other comprehensive income (loss) before reclassifications (40,401 ) — (7,173 ) (47,574 ) Amounts reclassified from accumulated other comprehensive income (loss) 8,397 15,265 5,428 29,090 Net other comprehensive income (loss) for the period (32,004 ) 15,265 (1,745 ) (18,484 ) Ending balance, September 30, 2018 ($46,878 ) ($574,661 ) ($10,587 ) ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2019 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Ending balance, December 31, 2018 ($23,135 ) ($531,922 ) ($2,116 ) ($557,173 ) Implementation of accounting standards (7,685 ) — 879 (6,806 ) Beginning balance, January 1, 2019 ($30,820 ) ($531,922 ) ($1,237 ) ($563,979 ) Other comprehensive income (loss) before reclassifications 122,481 — 37,724 160,205 Amounts reclassified from accumulated other comprehensive income (loss) (60,028 ) 48,510 (4,480 ) (15,998 ) Net other comprehensive income (loss) for the period 62,453 48,510 33,244 144,207 Ending balance, September 30, 2019 $31,633 ($483,412 ) $32,007 ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Ending balance, December 31, 2017 ($37,477 ) ($531,099 ) $545,045 ($23,531 ) Implementation of accounting standards — — (632,617 ) (632,617 ) Beginning balance, January 1, 2018 ($37,477 ) ($531,099 ) ($87,572 ) ($656,148 ) Other comprehensive income (loss) before reclassifications (31,816 ) — (50,958 ) (82,774 ) Amounts reclassified from accumulated other comprehensive income (loss) 30,171 47,404 13,716 91,291 Net other comprehensive income (loss) for the period (1,645 ) 47,404 (37,242 ) 8,517 Reclassification pursuant to ASU 2018-02 (7,756 ) (90,966 ) 114,227 15,505 Ending balance, September 30, 2018 ($46,878 ) ($574,661 ) ($10,587 ) ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2019 and 2018: Pension and Other 2019 2018 (In Thousands) Beginning balance, July 1, ($8,091 ) ($57,451 ) Amounts reclassified from accumulated other (969 ) (500 ) Net other comprehensive income (loss) for the period (969 ) (500 ) Ending balance, September 30, ($9,060 ) ($57,951 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2019 and 2018: Pension and Other 2019 2018 (In Thousands) Beginning balance, January 1, ($6,153 ) ($46,400 ) Amounts reclassified from accumulated other (2,907 ) (1,502 ) Net other comprehensive income (loss) for the period (2,907 ) (1,502 ) Reclassification pursuant to ASU 2018-02 — (10,049 ) Ending balance, September 30, ($9,060 ) ($57,951 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended September 30, 2019 and 2018 are as follows: Amounts reclassified Income Statement Location 2019 2018 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $18,925 ($10,566 ) Competitive business operating revenues Interest rate swaps (48 ) (63 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 18,877 (10,629 ) (3,964 ) 2,232 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $14,913 ($8,397 ) Pension and other postretirement liabilities Amortization of prior-service credit $5,325 $5,425 (a) Amortization of loss (20,919 ) (24,740 ) (a) Settlement loss (16,630 ) (76 ) (a) Total amortization (32,224 ) (19,391 ) 6,760 4,126 Income taxes Total amortization (net of tax) ($25,464 ) ($15,265 ) Net unrealized investment gain (loss) Realized gain (loss) $4,872 ($8,589 ) Interest and investment income (1,793 ) 3,161 Income taxes Total realized investment gain (loss) (net of tax) $3,079 ($5,428 ) Total reclassifications for the period (net of tax) ($7,472 ) ($29,090 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the nine months ended September 30, 2019 and 2018 are as follows: Amounts reclassified from AOCI Income Statement Location 2019 2018 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $76,129 ($37,913 ) Competitive business operating revenues Interest rate swaps (145 ) (278 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 75,984 (38,191 ) (15,956 ) 8,020 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $60,028 ($30,171 ) Pension and other postretirement liabilities Amortization of prior-service credit $15,977 $16,278 (a) Amortization of loss (58,888 ) (74,503 ) (a) Settlement loss (18,685 ) (2,098 ) (a) Total amortization (61,596 ) (60,323 ) 13,086 12,919 Income taxes Total amortization (net of tax) ($48,510 ) ($47,404 ) Net unrealized investment gain (loss) Realized gain (loss) $7,088 ($21,703 ) Interest and investment income (2,608 ) 7,987 Income taxes Total realized investment gain (loss) (net of tax) $4,480 ($13,716 ) Total reclassifications for the period (net of tax) $15,998 ($91,291 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended September 30, 2019 and 2018 are as follows: Amounts reclassified Income Statement Location 2019 2018 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,837 $1,934 (a) Amortization of loss (526 ) (1,257 ) (a) Total amortization 1,311 677 (342 ) (177 ) Income taxes Total amortization (net of tax) 969 500 Total reclassifications for the period (net of tax) $969 $500 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the nine months ended September 30, 2019 and 2018 are as follows: Amounts reclassified Income Statement Location 2019 2018 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,511 $5,802 (a) Amortization of loss (1,578 ) (3,770 ) (a) Total amortization 3,933 2,032 (1,026 ) (530 ) Income taxes Total amortization (net of tax) 2,907 1,502 Total reclassifications for the period (net of tax) $2,907 $1,502 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Preferred Stock In September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of September 30, 2019. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share. Accounting standards regarding the classification and measurement of redeemable securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem their securities, even if the likelihood of occurrence of these circumstances is considered remote. The outstanding preferred stock of Entergy Texas has protective rights with respect to unpaid dividends but provides for the election of board members that would not constitute a majority of the board, and the preferred stock of Entergy Texas is therefore classified as a component of equity.

Revolving Credit Facilities, Li

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	9 Months Ended
	Sep. 30, 2019
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 (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 September 2024. 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 nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $155 $6 $3,339 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At September 30, 2019 , Entergy Corporation had approximately $1,918 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2019 Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.17% $— $— Entergy Arkansas September 2024 $150 million (c) 3.17% $— $— Entergy Louisiana September 2024 $350 million (c) 3.17% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.54% $— $— Entergy Mississippi May 2020 $35 million (d) 3.54% $— $— Entergy Mississippi May 2020 $10 million (d) 3.54% $— $— Entergy New Orleans November 2021 $25 million (c) 3.32% $— $0.8 million Entergy Texas September 2024 $150 million (c) 3.54% $— $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 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 0.225% 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 uncommitted standby letter of credit facilities 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 September 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $11.7 million Entergy Mississippi $65 million 0.70% $8.1 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $26.2 million (a) As of September 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits for Entergy New Orleans are effective through October 31, 2021. The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy are effective through November 8, 2020. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (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 $— Entergy New Orleans $150 $46 Entergy Texas $200 $— System Energy $200 $— Vermont Yankee Asset Retirement Management, LLC Credit Facility In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, 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 November 2020. The commitment fee is currently 0.20% of the undrawn commitment amount. As of September 30, 2019 , $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein 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 September 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.41% $30.3 Entergy Louisiana River Bend VIE September 2021 $105 3.37% $84.3 Entergy Louisiana Waterford VIE September 2021 $105 3.41% $65.5 System Energy VIE September 2021 $120 3.42% $53.6 (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 0.10% 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 are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.42% Series J due April 2021 $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In March 2019, Entergy Arkansas issued $350 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas is using the proceeds for general corporate purposes. (Entergy Louisiana) In March 2019, Entergy Louisiana issued $525 million of 4.20% Series mortgage bonds due April 2050. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and the St. Charles Power Station, and for general corporate purposes. (Entergy Mississippi) In June 2019, Entergy Mississippi issued $300 million of 3.85% Series mortgage bonds due June 2049. Entergy Mississippi used the proceeds to repay, at maturity, its $150 million of 6.64% Series mortgage bonds due July 2019 and for general corporate purposes. (Entergy Texas) In January 2019, Entergy Texas issued $300 million of 4.0% Series mortgage bonds due March 2029 and $400 million of 4.5% Series mortgage bonds due March 2039. Entergy Texas used the proceeds to repay, at maturity, its $500 million of 7.125% Series mortgage bonds due February 2019 and for general corporate purposes. In September 2019, Entergy Texas issued $300 million of 3.55% Series mortgage bonds due September 2049. Entergy Texas is using the proceeds, together with other funds, to finance the construction of the Montgomery County Power Station, and for general corporate purposes. (System Energy) In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,458,026 $18,628,268 Entergy Arkansas $3,538,384 $3,621,073 Entergy Louisiana $7,344,160 $8,038,675 Entergy Mississippi $1,469,454 $1,586,199 Entergy New Orleans $478,619 $522,688 Entergy Texas $1,938,303 $2,128,842 System Energy $570,001 $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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, 2018 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,168,312 $15,880,239 Entergy Arkansas $3,225,759 $3,002,627 Entergy Louisiana $6,805,768 $6,834,134 Entergy Mississippi $1,325,750 $1,276,452 Entergy New Orleans $483,704 $491,569 Entergy Texas $1,513,735 $1,528,828 System Energy $630,750 $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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	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 September 2024. 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 nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $155 $6 $3,339 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At September 30, 2019 , Entergy Corporation had approximately $1,918 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2019 Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.17% $— $— Entergy Arkansas September 2024 $150 million (c) 3.17% $— $— Entergy Louisiana September 2024 $350 million (c) 3.17% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.54% $— $— Entergy Mississippi May 2020 $35 million (d) 3.54% $— $— Entergy Mississippi May 2020 $10 million (d) 3.54% $— $— Entergy New Orleans November 2021 $25 million (c) 3.32% $— $0.8 million Entergy Texas September 2024 $150 million (c) 3.54% $— $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 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 0.225% 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 uncommitted standby letter of credit facilities 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 September 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $11.7 million Entergy Mississippi $65 million 0.70% $8.1 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $26.2 million (a) As of September 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits for Entergy New Orleans are effective through October 31, 2021. The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy are effective through November 8, 2020. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (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 $— Entergy New Orleans $150 $46 Entergy Texas $200 $— System Energy $200 $— Vermont Yankee Asset Retirement Management, LLC Credit Facility In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, 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 November 2020. The commitment fee is currently 0.20% of the undrawn commitment amount. As of September 30, 2019 , $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein 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 September 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.41% $30.3 Entergy Louisiana River Bend VIE September 2021 $105 3.37% $84.3 Entergy Louisiana Waterford VIE September 2021 $105 3.41% $65.5 System Energy VIE September 2021 $120 3.42% $53.6 (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 0.10% 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 are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.42% Series J due April 2021 $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In March 2019, Entergy Arkansas issued $350 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas is using the proceeds for general corporate purposes. (Entergy Louisiana) In March 2019, Entergy Louisiana issued $525 million of 4.20% Series mortgage bonds due April 2050. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and the St. Charles Power Station, and for general corporate purposes. (Entergy Mississippi) In June 2019, Entergy Mississippi issued $300 million of 3.85% Series mortgage bonds due June 2049. Entergy Mississippi used the proceeds to repay, at maturity, its $150 million of 6.64% Series mortgage bonds due July 2019 and for general corporate purposes. (Entergy Texas) In January 2019, Entergy Texas issued $300 million of 4.0% Series mortgage bonds due March 2029 and $400 million of 4.5% Series mortgage bonds due March 2039. Entergy Texas used the proceeds to repay, at maturity, its $500 million of 7.125% Series mortgage bonds due February 2019 and for general corporate purposes. In September 2019, Entergy Texas issued $300 million of 3.55% Series mortgage bonds due September 2049. Entergy Texas is using the proceeds, together with other funds, to finance the construction of the Montgomery County Power Station, and for general corporate purposes. (System Energy) In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,458,026 $18,628,268 Entergy Arkansas $3,538,384 $3,621,073 Entergy Louisiana $7,344,160 $8,038,675 Entergy Mississippi $1,469,454 $1,586,199 Entergy New Orleans $478,619 $522,688 Entergy Texas $1,938,303 $2,128,842 System Energy $570,001 $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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, 2018 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,168,312 $15,880,239 Entergy Arkansas $3,225,759 $3,002,627 Entergy Louisiana $6,805,768 $6,834,134 Entergy Mississippi $1,325,750 $1,276,452 Entergy New Orleans $483,704 $491,569 Entergy Texas $1,513,735 $1,528,828 System Energy $630,750 $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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	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 September 2024. 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 nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $155 $6 $3,339 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At September 30, 2019 , Entergy Corporation had approximately $1,918 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2019 Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.17% $— $— Entergy Arkansas September 2024 $150 million (c) 3.17% $— $— Entergy Louisiana September 2024 $350 million (c) 3.17% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.54% $— $— Entergy Mississippi May 2020 $35 million (d) 3.54% $— $— Entergy Mississippi May 2020 $10 million (d) 3.54% $— $— Entergy New Orleans November 2021 $25 million (c) 3.32% $— $0.8 million Entergy Texas September 2024 $150 million (c) 3.54% $— $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 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 0.225% 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 uncommitted standby letter of credit facilities 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 September 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $11.7 million Entergy Mississippi $65 million 0.70% $8.1 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $26.2 million (a) As of September 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits for Entergy New Orleans are effective through October 31, 2021. The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy are effective through November 8, 2020. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (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 $— Entergy New Orleans $150 $46 Entergy Texas $200 $— System Energy $200 $— Vermont Yankee Asset Retirement Management, LLC Credit Facility In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, 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 November 2020. The commitment fee is currently 0.20% of the undrawn commitment amount. As of September 30, 2019 , $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein 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 September 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.41% $30.3 Entergy Louisiana River Bend VIE September 2021 $105 3.37% $84.3 Entergy Louisiana Waterford VIE September 2021 $105 3.41% $65.5 System Energy VIE September 2021 $120 3.42% $53.6 (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 0.10% 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 are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.42% Series J due April 2021 $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In March 2019, Entergy Arkansas issued $350 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas is using the proceeds for general corporate purposes. (Entergy Louisiana) In March 2019, Entergy Louisiana issued $525 million of 4.20% Series mortgage bonds due April 2050. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and the St. Charles Power Station, and for general corporate purposes. (Entergy Mississippi) In June 2019, Entergy Mississippi issued $300 million of 3.85% Series mortgage bonds due June 2049. Entergy Mississippi used the proceeds to repay, at maturity, its $150 million of 6.64% Series mortgage bonds due July 2019 and for general corporate purposes. (Entergy Texas) In January 2019, Entergy Texas issued $300 million of 4.0% Series mortgage bonds due March 2029 and $400 million of 4.5% Series mortgage bonds due March 2039. Entergy Texas used the proceeds to repay, at maturity, its $500 million of 7.125% Series mortgage bonds due February 2019 and for general corporate purposes. In September 2019, Entergy Texas issued $300 million of 3.55% Series mortgage bonds due September 2049. Entergy Texas is using the proceeds, together with other funds, to finance the construction of the Montgomery County Power Station, and for general corporate purposes. (System Energy) In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,458,026 $18,628,268 Entergy Arkansas $3,538,384 $3,621,073 Entergy Louisiana $7,344,160 $8,038,675 Entergy Mississippi $1,469,454 $1,586,199 Entergy New Orleans $478,619 $522,688 Entergy Texas $1,938,303 $2,128,842 System Energy $570,001 $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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, 2018 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,168,312 $15,880,239 Entergy Arkansas $3,225,759 $3,002,627 Entergy Louisiana $6,805,768 $6,834,134 Entergy Mississippi $1,325,750 $1,276,452 Entergy New Orleans $483,704 $491,569 Entergy Texas $1,513,735 $1,528,828 System Energy $630,750 $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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	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 September 2024. 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 nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $155 $6 $3,339 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At September 30, 2019 , Entergy Corporation had approximately $1,918 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2019 Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.17% $— $— Entergy Arkansas September 2024 $150 million (c) 3.17% $— $— Entergy Louisiana September 2024 $350 million (c) 3.17% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.54% $— $— Entergy Mississippi May 2020 $35 million (d) 3.54% $— $— Entergy Mississippi May 2020 $10 million (d) 3.54% $— $— Entergy New Orleans November 2021 $25 million (c) 3.32% $— $0.8 million Entergy Texas September 2024 $150 million (c) 3.54% $— $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 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 0.225% 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 uncommitted standby letter of credit facilities 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 September 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $11.7 million Entergy Mississippi $65 million 0.70% $8.1 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $26.2 million (a) As of September 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits for Entergy New Orleans are effective through October 31, 2021. The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy are effective through November 8, 2020. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (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 $— Entergy New Orleans $150 $46 Entergy Texas $200 $— System Energy $200 $— Vermont Yankee Asset Retirement Management, LLC Credit Facility In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, 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 November 2020. The commitment fee is currently 0.20% of the undrawn commitment amount. As of September 30, 2019 , $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein 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 September 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.41% $30.3 Entergy Louisiana River Bend VIE September 2021 $105 3.37% $84.3 Entergy Louisiana Waterford VIE September 2021 $105 3.41% $65.5 System Energy VIE September 2021 $120 3.42% $53.6 (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 0.10% 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 are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.42% Series J due April 2021 $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In March 2019, Entergy Arkansas issued $350 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas is using the proceeds for general corporate purposes. (Entergy Louisiana) In March 2019, Entergy Louisiana issued $525 million of 4.20% Series mortgage bonds due April 2050. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and the St. Charles Power Station, and for general corporate purposes. (Entergy Mississippi) In June 2019, Entergy Mississippi issued $300 million of 3.85% Series mortgage bonds due June 2049. Entergy Mississippi used the proceeds to repay, at maturity, its $150 million of 6.64% Series mortgage bonds due July 2019 and for general corporate purposes. (Entergy Texas) In January 2019, Entergy Texas issued $300 million of 4.0% Series mortgage bonds due March 2029 and $400 million of 4.5% Series mortgage bonds due March 2039. Entergy Texas used the proceeds to repay, at maturity, its $500 million of 7.125% Series mortgage bonds due February 2019 and for general corporate purposes. In September 2019, Entergy Texas issued $300 million of 3.55% Series mortgage bonds due September 2049. Entergy Texas is using the proceeds, together with other funds, to finance the construction of the Montgomery County Power Station, and for general corporate purposes. (System Energy) In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,458,026 $18,628,268 Entergy Arkansas $3,538,384 $3,621,073 Entergy Louisiana $7,344,160 $8,038,675 Entergy Mississippi $1,469,454 $1,586,199 Entergy New Orleans $478,619 $522,688 Entergy Texas $1,938,303 $2,128,842 System Energy $570,001 $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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, 2018 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,168,312 $15,880,239 Entergy Arkansas $3,225,759 $3,002,627 Entergy Louisiana $6,805,768 $6,834,134 Entergy Mississippi $1,325,750 $1,276,452 Entergy New Orleans $483,704 $491,569 Entergy Texas $1,513,735 $1,528,828 System Energy $630,750 $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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	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 September 2024. 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 nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $155 $6 $3,339 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At September 30, 2019 , Entergy Corporation had approximately $1,918 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2019 Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.17% $— $— Entergy Arkansas September 2024 $150 million (c) 3.17% $— $— Entergy Louisiana September 2024 $350 million (c) 3.17% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.54% $— $— Entergy Mississippi May 2020 $35 million (d) 3.54% $— $— Entergy Mississippi May 2020 $10 million (d) 3.54% $— $— Entergy New Orleans November 2021 $25 million (c) 3.32% $— $0.8 million Entergy Texas September 2024 $150 million (c) 3.54% $— $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 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 0.225% 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 uncommitted standby letter of credit facilities 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 September 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $11.7 million Entergy Mississippi $65 million 0.70% $8.1 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $26.2 million (a) As of September 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits for Entergy New Orleans are effective through October 31, 2021. The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy are effective through November 8, 2020. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (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 $— Entergy New Orleans $150 $46 Entergy Texas $200 $— System Energy $200 $— Vermont Yankee Asset Retirement Management, LLC Credit Facility In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, 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 November 2020. The commitment fee is currently 0.20% of the undrawn commitment amount. As of September 30, 2019 , $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein 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 September 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.41% $30.3 Entergy Louisiana River Bend VIE September 2021 $105 3.37% $84.3 Entergy Louisiana Waterford VIE September 2021 $105 3.41% $65.5 System Energy VIE September 2021 $120 3.42% $53.6 (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 0.10% 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 are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.42% Series J due April 2021 $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In March 2019, Entergy Arkansas issued $350 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas is using the proceeds for general corporate purposes. (Entergy Louisiana) In March 2019, Entergy Louisiana issued $525 million of 4.20% Series mortgage bonds due April 2050. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and the St. Charles Power Station, and for general corporate purposes. (Entergy Mississippi) In June 2019, Entergy Mississippi issued $300 million of 3.85% Series mortgage bonds due June 2049. Entergy Mississippi used the proceeds to repay, at maturity, its $150 million of 6.64% Series mortgage bonds due July 2019 and for general corporate purposes. (Entergy Texas) In January 2019, Entergy Texas issued $300 million of 4.0% Series mortgage bonds due March 2029 and $400 million of 4.5% Series mortgage bonds due March 2039. Entergy Texas used the proceeds to repay, at maturity, its $500 million of 7.125% Series mortgage bonds due February 2019 and for general corporate purposes. In September 2019, Entergy Texas issued $300 million of 3.55% Series mortgage bonds due September 2049. Entergy Texas is using the proceeds, together with other funds, to finance the construction of the Montgomery County Power Station, and for general corporate purposes. (System Energy) In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,458,026 $18,628,268 Entergy Arkansas $3,538,384 $3,621,073 Entergy Louisiana $7,344,160 $8,038,675 Entergy Mississippi $1,469,454 $1,586,199 Entergy New Orleans $478,619 $522,688 Entergy Texas $1,938,303 $2,128,842 System Energy $570,001 $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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, 2018 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,168,312 $15,880,239 Entergy Arkansas $3,225,759 $3,002,627 Entergy Louisiana $6,805,768 $6,834,134 Entergy Mississippi $1,325,750 $1,276,452 Entergy New Orleans $483,704 $491,569 Entergy Texas $1,513,735 $1,528,828 System Energy $630,750 $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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	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 September 2024. 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 nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $155 $6 $3,339 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At September 30, 2019 , Entergy Corporation had approximately $1,918 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2019 Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.17% $— $— Entergy Arkansas September 2024 $150 million (c) 3.17% $— $— Entergy Louisiana September 2024 $350 million (c) 3.17% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.54% $— $— Entergy Mississippi May 2020 $35 million (d) 3.54% $— $— Entergy Mississippi May 2020 $10 million (d) 3.54% $— $— Entergy New Orleans November 2021 $25 million (c) 3.32% $— $0.8 million Entergy Texas September 2024 $150 million (c) 3.54% $— $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 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 0.225% 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 uncommitted standby letter of credit facilities 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 September 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $11.7 million Entergy Mississippi $65 million 0.70% $8.1 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $26.2 million (a) As of September 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits for Entergy New Orleans are effective through October 31, 2021. The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy are effective through November 8, 2020. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (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 $— Entergy New Orleans $150 $46 Entergy Texas $200 $— System Energy $200 $— Vermont Yankee Asset Retirement Management, LLC Credit Facility In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, 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 November 2020. The commitment fee is currently 0.20% of the undrawn commitment amount. As of September 30, 2019 , $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein 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 September 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.41% $30.3 Entergy Louisiana River Bend VIE September 2021 $105 3.37% $84.3 Entergy Louisiana Waterford VIE September 2021 $105 3.41% $65.5 System Energy VIE September 2021 $120 3.42% $53.6 (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 0.10% 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 are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.42% Series J due April 2021 $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In March 2019, Entergy Arkansas issued $350 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas is using the proceeds for general corporate purposes. (Entergy Louisiana) In March 2019, Entergy Louisiana issued $525 million of 4.20% Series mortgage bonds due April 2050. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and the St. Charles Power Station, and for general corporate purposes. (Entergy Mississippi) In June 2019, Entergy Mississippi issued $300 million of 3.85% Series mortgage bonds due June 2049. Entergy Mississippi used the proceeds to repay, at maturity, its $150 million of 6.64% Series mortgage bonds due July 2019 and for general corporate purposes. (Entergy Texas) In January 2019, Entergy Texas issued $300 million of 4.0% Series mortgage bonds due March 2029 and $400 million of 4.5% Series mortgage bonds due March 2039. Entergy Texas used the proceeds to repay, at maturity, its $500 million of 7.125% Series mortgage bonds due February 2019 and for general corporate purposes. In September 2019, Entergy Texas issued $300 million of 3.55% Series mortgage bonds due September 2049. Entergy Texas is using the proceeds, together with other funds, to finance the construction of the Montgomery County Power Station, and for general corporate purposes. (System Energy) In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,458,026 $18,628,268 Entergy Arkansas $3,538,384 $3,621,073 Entergy Louisiana $7,344,160 $8,038,675 Entergy Mississippi $1,469,454 $1,586,199 Entergy New Orleans $478,619 $522,688 Entergy Texas $1,938,303 $2,128,842 System Energy $570,001 $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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, 2018 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,168,312 $15,880,239 Entergy Arkansas $3,225,759 $3,002,627 Entergy Louisiana $6,805,768 $6,834,134 Entergy Mississippi $1,325,750 $1,276,452 Entergy New Orleans $483,704 $491,569 Entergy Texas $1,513,735 $1,528,828 System Energy $630,750 $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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	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 September 2024. 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 nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $155 $6 $3,339 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At September 30, 2019 , Entergy Corporation had approximately $1,918 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2019 Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.17% $— $— Entergy Arkansas September 2024 $150 million (c) 3.17% $— $— Entergy Louisiana September 2024 $350 million (c) 3.17% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.54% $— $— Entergy Mississippi May 2020 $35 million (d) 3.54% $— $— Entergy Mississippi May 2020 $10 million (d) 3.54% $— $— Entergy New Orleans November 2021 $25 million (c) 3.32% $— $0.8 million Entergy Texas September 2024 $150 million (c) 3.54% $— $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 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 0.225% 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 uncommitted standby letter of credit facilities 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 September 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $11.7 million Entergy Mississippi $65 million 0.70% $8.1 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $26.2 million (a) As of September 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits for Entergy New Orleans are effective through October 31, 2021. The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy are effective through November 8, 2020. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (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 $— Entergy New Orleans $150 $46 Entergy Texas $200 $— System Energy $200 $— Vermont Yankee Asset Retirement Management, LLC Credit Facility In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, 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 November 2020. The commitment fee is currently 0.20% of the undrawn commitment amount. As of September 30, 2019 , $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein 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 September 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.41% $30.3 Entergy Louisiana River Bend VIE September 2021 $105 3.37% $84.3 Entergy Louisiana Waterford VIE September 2021 $105 3.41% $65.5 System Energy VIE September 2021 $120 3.42% $53.6 (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 0.10% 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 are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.42% Series J due April 2021 $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In March 2019, Entergy Arkansas issued $350 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas is using the proceeds for general corporate purposes. (Entergy Louisiana) In March 2019, Entergy Louisiana issued $525 million of 4.20% Series mortgage bonds due April 2050. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and the St. Charles Power Station, and for general corporate purposes. (Entergy Mississippi) In June 2019, Entergy Mississippi issued $300 million of 3.85% Series mortgage bonds due June 2049. Entergy Mississippi used the proceeds to repay, at maturity, its $150 million of 6.64% Series mortgage bonds due July 2019 and for general corporate purposes. (Entergy Texas) In January 2019, Entergy Texas issued $300 million of 4.0% Series mortgage bonds due March 2029 and $400 million of 4.5% Series mortgage bonds due March 2039. Entergy Texas used the proceeds to repay, at maturity, its $500 million of 7.125% Series mortgage bonds due February 2019 and for general corporate purposes. In September 2019, Entergy Texas issued $300 million of 3.55% Series mortgage bonds due September 2049. Entergy Texas is using the proceeds, together with other funds, to finance the construction of the Montgomery County Power Station, and for general corporate purposes. (System Energy) In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,458,026 $18,628,268 Entergy Arkansas $3,538,384 $3,621,073 Entergy Louisiana $7,344,160 $8,038,675 Entergy Mississippi $1,469,454 $1,586,199 Entergy New Orleans $478,619 $522,688 Entergy Texas $1,938,303 $2,128,842 System Energy $570,001 $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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, 2018 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,168,312 $15,880,239 Entergy Arkansas $3,225,759 $3,002,627 Entergy Louisiana $6,805,768 $6,834,134 Entergy Mississippi $1,325,750 $1,276,452 Entergy New Orleans $483,704 $491,569 Entergy Texas $1,513,735 $1,528,828 System Energy $630,750 $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Stock-Based Compensation

Stock-Based Compensation	9 Months Ended
	Sep. 30, 2019
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 693,161 shares of its common stock under the 2015 Equity Ownership Plan during the first quarter 2019 with a fair value of $8.32 per option. As of September 30, 2019 , there were options on 2,515,896 shares of common stock outstanding with a weighted-average exercise price of $78.53 . 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 September 30, 2019 . The aggregate intrinsic value of the stock options outstanding as of September 30, 2019 was $97.7 million . The following table includes financial information for outstanding stock options for the three months ended September 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $0.9 $1.1 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 $0.1 The following table includes financial information for outstanding stock options for the nine months ended September 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $2.9 $3.3 Tax benefit recognized in Entergy’s net income $0.7 $0.8 Compensation cost capitalized as part of fixed assets and materials and supplies $1.0 $0.5 Other Equity Awards In January 2019, the Board approved and Entergy granted 355,537 restricted stock awards and 180,824 long-term incentive awards under the 2015 Equity Ownership Plan. The restricted stock awards were made effective as of January 31, 2019 and were valued at $89.19 per share, which was the closing price of Entergy’s common stock on that date. One-third of the restricted stock awards will vest upon each anniversary of the grant 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. 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. For the 2019-2021 performance period, performance will be measured based eighty percent on relative total shareholder return and twenty percent on a cumulative adjusted earnings per share metric. The performance units were granted as of January 31, 2019 and eighty percent were valued at $102.07 per share based on various factors, primarily market conditions; and twenty percent were valued at $89.19 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 September 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $8.4 $8.5 Tax benefit recognized in Entergy’s net income $2.1 $2.2 Compensation cost capitalized as part of fixed assets and materials and supplies $3.0 $2.5 The following table includes financial information for other outstanding equity awards for the nine months ended September 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $25.6 $26.0 Tax benefit recognized in Entergy’s net income $6.5 $6.6 Compensation cost capitalized as part of fixed assets and materials and supplies $8.8 $7.3

Retirement And Other Postretire

Retirement And Other Postretirement Benefits	9 Months Ended
	Sep. 30, 2019
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 third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,553 $38,752 Interest cost on projected benefit obligation 73,261 66,854 Expected return on assets (103,751 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 60,395 68,526 Settlement charges 16,291 — Net pension costs $79,749 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $100,766 $116,256 Interest cost on projected benefit obligation 221,114 200,562 Expected return on assets (311,494 ) (331,605 ) Amortization of prior service cost — 297 Amortization of net loss 177,233 205,578 Settlement charges 17,591 — Net pension costs $205,210 $191,088 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,260 $7,284 $1,629 $568 $1,350 $1,549 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,873 3,613 3,364 Expected return on assets (20,177 ) (22,651 ) (5,969 ) (2,696 ) (5,862 ) (4,678 ) Amortization of net loss 11,840 11,643 3,104 1,529 2,334 2,850 Net pension cost $11,098 $12,158 $2,832 $1,274 $1,435 $3,085 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projected benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of net loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,782 $21,852 $4,887 $1,706 $4,050 $4,649 Interest cost on projected benefit obligation 42,525 47,646 12,204 5,621 10,837 10,091 Expected return on assets (60,529 ) (67,955 ) (17,905 ) (8,089 ) (17,586 ) (14,032 ) Amortization of net loss 35,522 34,929 9,313 4,588 7,002 8,550 Net pension cost $33,300 $36,472 $8,499 $3,826 $4,303 $9,258 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projected benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of net loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.2 million in pension cost for its non-qualified pension plans in the third quarters of 2019 and 2018 , respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2019 and 2018 were settlement charges of $955 thousand and $212 thousand , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $16.3 million and $19.7 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 and 2018 were settlement charges of $4.6 million and $7 million , respectively, related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $67 $38 $69 $5 $119 2018 $114 $42 $73 $20 $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $211 $122 $257 $16 $365 2018 $369 $138 $230 $62 $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $4,675 $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975 12,681 Expected return on assets (9,562 ) (10,373 ) Amortization of prior service credit (8,844 ) (9,251 ) Amortization of net loss 358 3,432 Net other postretirement benefit cost (income) ($1,398 ) $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $14,025 $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925 38,043 Expected return on assets (28,686 ) (31,119 ) Amortization of prior service credit (26,532 ) (27,753 ) Amortization of net loss 1,074 10,296 Net other postretirement benefit cost (income) ($4,194 ) $9,813 The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $591 $1,160 $262 $92 $236 $243 Interest cost on APBO 1,807 2,666 670 395 854 476 Expected return on assets (3,991 ) — (1,199 ) (1,237 ) (2,276 ) (697 ) Amortization of prior service credit (1,238 ) (1,837 ) (439 ) (171 ) (561 ) (363 ) Amortization of net (gain) loss 144 (174 ) 181 58 121 89 Net other postretirement benefit cost (income) ($2,687 ) $1,815 ($525 ) ($863 ) ($1,626 ) ($252 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of net loss 289 388 377 34 206 233 Net other postretirement benefit cost (income) ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,773 $3,480 $786 $276 $708 $729 Interest cost on APBO 5,421 7,998 2,010 1,185 2,562 1,428 Expected return on assets (11,973 ) — (3,597 ) (3,711 ) (6,828 ) (2,091 ) Amortization of prior service credit (3,714 ) (5,511 ) (1,317 ) (513 ) (1,683 ) (1,089 ) Amortization of net (gain) loss 432 (522 ) 543 174 363 267 Net other postretirement benefit cost (income) ($8,061 ) $5,445 ($1,575 ) ($2,589 ) ($4,878 ) ($756 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of net loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost (income) ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 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 third quarters of 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,375 ($50 ) $5,325 Amortization of net gain (loss) (20,686 ) 308 (541 ) (20,919 ) Settlement loss (16,257 ) — (373 ) (16,630 ) ($36,943 ) $5,683 ($964 ) ($32,224 ) Entergy Louisiana Amortization of prior service credit $— $1,837 $— $1,837 Amortization of net gain (loss) (699 ) 174 (1 ) (526 ) ($699 ) $2,011 ($1 ) $1,311 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($297 ) $16,786 ($211 ) $16,278 Amortization of net loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of net loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019. As of September 30, 2019 , Entergy had contributed $123.1 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 2019 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2019 pension contributions $27,112 $26,451 $7,701 $1,800 $1,645 $8,285 Pension contributions made through September 2019 $18,222 $18,272 $5,186 $1,237 $1,192 $5,631 Remaining estimated pension contributions to be made in 2019 $8,890 $8,179 $2,515 $563 $453 $2,654
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 third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,553 $38,752 Interest cost on projected benefit obligation 73,261 66,854 Expected return on assets (103,751 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 60,395 68,526 Settlement charges 16,291 — Net pension costs $79,749 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $100,766 $116,256 Interest cost on projected benefit obligation 221,114 200,562 Expected return on assets (311,494 ) (331,605 ) Amortization of prior service cost — 297 Amortization of net loss 177,233 205,578 Settlement charges 17,591 — Net pension costs $205,210 $191,088 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,260 $7,284 $1,629 $568 $1,350 $1,549 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,873 3,613 3,364 Expected return on assets (20,177 ) (22,651 ) (5,969 ) (2,696 ) (5,862 ) (4,678 ) Amortization of net loss 11,840 11,643 3,104 1,529 2,334 2,850 Net pension cost $11,098 $12,158 $2,832 $1,274 $1,435 $3,085 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projected benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of net loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,782 $21,852 $4,887 $1,706 $4,050 $4,649 Interest cost on projected benefit obligation 42,525 47,646 12,204 5,621 10,837 10,091 Expected return on assets (60,529 ) (67,955 ) (17,905 ) (8,089 ) (17,586 ) (14,032 ) Amortization of net loss 35,522 34,929 9,313 4,588 7,002 8,550 Net pension cost $33,300 $36,472 $8,499 $3,826 $4,303 $9,258 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projected benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of net loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.2 million in pension cost for its non-qualified pension plans in the third quarters of 2019 and 2018 , respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2019 and 2018 were settlement charges of $955 thousand and $212 thousand , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $16.3 million and $19.7 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 and 2018 were settlement charges of $4.6 million and $7 million , respectively, related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $67 $38 $69 $5 $119 2018 $114 $42 $73 $20 $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $211 $122 $257 $16 $365 2018 $369 $138 $230 $62 $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $4,675 $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975 12,681 Expected return on assets (9,562 ) (10,373 ) Amortization of prior service credit (8,844 ) (9,251 ) Amortization of net loss 358 3,432 Net other postretirement benefit cost (income) ($1,398 ) $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $14,025 $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925 38,043 Expected return on assets (28,686 ) (31,119 ) Amortization of prior service credit (26,532 ) (27,753 ) Amortization of net loss 1,074 10,296 Net other postretirement benefit cost (income) ($4,194 ) $9,813 The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $591 $1,160 $262 $92 $236 $243 Interest cost on APBO 1,807 2,666 670 395 854 476 Expected return on assets (3,991 ) — (1,199 ) (1,237 ) (2,276 ) (697 ) Amortization of prior service credit (1,238 ) (1,837 ) (439 ) (171 ) (561 ) (363 ) Amortization of net (gain) loss 144 (174 ) 181 58 121 89 Net other postretirement benefit cost (income) ($2,687 ) $1,815 ($525 ) ($863 ) ($1,626 ) ($252 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of net loss 289 388 377 34 206 233 Net other postretirement benefit cost (income) ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,773 $3,480 $786 $276 $708 $729 Interest cost on APBO 5,421 7,998 2,010 1,185 2,562 1,428 Expected return on assets (11,973 ) — (3,597 ) (3,711 ) (6,828 ) (2,091 ) Amortization of prior service credit (3,714 ) (5,511 ) (1,317 ) (513 ) (1,683 ) (1,089 ) Amortization of net (gain) loss 432 (522 ) 543 174 363 267 Net other postretirement benefit cost (income) ($8,061 ) $5,445 ($1,575 ) ($2,589 ) ($4,878 ) ($756 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of net loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost (income) ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 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 third quarters of 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,375 ($50 ) $5,325 Amortization of net gain (loss) (20,686 ) 308 (541 ) (20,919 ) Settlement loss (16,257 ) — (373 ) (16,630 ) ($36,943 ) $5,683 ($964 ) ($32,224 ) Entergy Louisiana Amortization of prior service credit $— $1,837 $— $1,837 Amortization of net gain (loss) (699 ) 174 (1 ) (526 ) ($699 ) $2,011 ($1 ) $1,311 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($297 ) $16,786 ($211 ) $16,278 Amortization of net loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of net loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019. As of September 30, 2019 , Entergy had contributed $123.1 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 2019 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2019 pension contributions $27,112 $26,451 $7,701 $1,800 $1,645 $8,285 Pension contributions made through September 2019 $18,222 $18,272 $5,186 $1,237 $1,192 $5,631 Remaining estimated pension contributions to be made in 2019 $8,890 $8,179 $2,515 $563 $453 $2,654
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 third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,553 $38,752 Interest cost on projected benefit obligation 73,261 66,854 Expected return on assets (103,751 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 60,395 68,526 Settlement charges 16,291 — Net pension costs $79,749 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $100,766 $116,256 Interest cost on projected benefit obligation 221,114 200,562 Expected return on assets (311,494 ) (331,605 ) Amortization of prior service cost — 297 Amortization of net loss 177,233 205,578 Settlement charges 17,591 — Net pension costs $205,210 $191,088 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,260 $7,284 $1,629 $568 $1,350 $1,549 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,873 3,613 3,364 Expected return on assets (20,177 ) (22,651 ) (5,969 ) (2,696 ) (5,862 ) (4,678 ) Amortization of net loss 11,840 11,643 3,104 1,529 2,334 2,850 Net pension cost $11,098 $12,158 $2,832 $1,274 $1,435 $3,085 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projected benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of net loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,782 $21,852 $4,887 $1,706 $4,050 $4,649 Interest cost on projected benefit obligation 42,525 47,646 12,204 5,621 10,837 10,091 Expected return on assets (60,529 ) (67,955 ) (17,905 ) (8,089 ) (17,586 ) (14,032 ) Amortization of net loss 35,522 34,929 9,313 4,588 7,002 8,550 Net pension cost $33,300 $36,472 $8,499 $3,826 $4,303 $9,258 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projected benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of net loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.2 million in pension cost for its non-qualified pension plans in the third quarters of 2019 and 2018 , respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2019 and 2018 were settlement charges of $955 thousand and $212 thousand , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $16.3 million and $19.7 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 and 2018 were settlement charges of $4.6 million and $7 million , respectively, related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $67 $38 $69 $5 $119 2018 $114 $42 $73 $20 $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $211 $122 $257 $16 $365 2018 $369 $138 $230 $62 $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $4,675 $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975 12,681 Expected return on assets (9,562 ) (10,373 ) Amortization of prior service credit (8,844 ) (9,251 ) Amortization of net loss 358 3,432 Net other postretirement benefit cost (income) ($1,398 ) $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $14,025 $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925 38,043 Expected return on assets (28,686 ) (31,119 ) Amortization of prior service credit (26,532 ) (27,753 ) Amortization of net loss 1,074 10,296 Net other postretirement benefit cost (income) ($4,194 ) $9,813 The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $591 $1,160 $262 $92 $236 $243 Interest cost on APBO 1,807 2,666 670 395 854 476 Expected return on assets (3,991 ) — (1,199 ) (1,237 ) (2,276 ) (697 ) Amortization of prior service credit (1,238 ) (1,837 ) (439 ) (171 ) (561 ) (363 ) Amortization of net (gain) loss 144 (174 ) 181 58 121 89 Net other postretirement benefit cost (income) ($2,687 ) $1,815 ($525 ) ($863 ) ($1,626 ) ($252 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of net loss 289 388 377 34 206 233 Net other postretirement benefit cost (income) ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,773 $3,480 $786 $276 $708 $729 Interest cost on APBO 5,421 7,998 2,010 1,185 2,562 1,428 Expected return on assets (11,973 ) — (3,597 ) (3,711 ) (6,828 ) (2,091 ) Amortization of prior service credit (3,714 ) (5,511 ) (1,317 ) (513 ) (1,683 ) (1,089 ) Amortization of net (gain) loss 432 (522 ) 543 174 363 267 Net other postretirement benefit cost (income) ($8,061 ) $5,445 ($1,575 ) ($2,589 ) ($4,878 ) ($756 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of net loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost (income) ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 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 third quarters of 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,375 ($50 ) $5,325 Amortization of net gain (loss) (20,686 ) 308 (541 ) (20,919 ) Settlement loss (16,257 ) — (373 ) (16,630 ) ($36,943 ) $5,683 ($964 ) ($32,224 ) Entergy Louisiana Amortization of prior service credit $— $1,837 $— $1,837 Amortization of net gain (loss) (699 ) 174 (1 ) (526 ) ($699 ) $2,011 ($1 ) $1,311 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($297 ) $16,786 ($211 ) $16,278 Amortization of net loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of net loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019. As of September 30, 2019 , Entergy had contributed $123.1 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 2019 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2019 pension contributions $27,112 $26,451 $7,701 $1,800 $1,645 $8,285 Pension contributions made through September 2019 $18,222 $18,272 $5,186 $1,237 $1,192 $5,631 Remaining estimated pension contributions to be made in 2019 $8,890 $8,179 $2,515 $563 $453 $2,654
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 third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,553 $38,752 Interest cost on projected benefit obligation 73,261 66,854 Expected return on assets (103,751 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 60,395 68,526 Settlement charges 16,291 — Net pension costs $79,749 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $100,766 $116,256 Interest cost on projected benefit obligation 221,114 200,562 Expected return on assets (311,494 ) (331,605 ) Amortization of prior service cost — 297 Amortization of net loss 177,233 205,578 Settlement charges 17,591 — Net pension costs $205,210 $191,088 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,260 $7,284 $1,629 $568 $1,350 $1,549 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,873 3,613 3,364 Expected return on assets (20,177 ) (22,651 ) (5,969 ) (2,696 ) (5,862 ) (4,678 ) Amortization of net loss 11,840 11,643 3,104 1,529 2,334 2,850 Net pension cost $11,098 $12,158 $2,832 $1,274 $1,435 $3,085 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projected benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of net loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,782 $21,852 $4,887 $1,706 $4,050 $4,649 Interest cost on projected benefit obligation 42,525 47,646 12,204 5,621 10,837 10,091 Expected return on assets (60,529 ) (67,955 ) (17,905 ) (8,089 ) (17,586 ) (14,032 ) Amortization of net loss 35,522 34,929 9,313 4,588 7,002 8,550 Net pension cost $33,300 $36,472 $8,499 $3,826 $4,303 $9,258 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projected benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of net loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.2 million in pension cost for its non-qualified pension plans in the third quarters of 2019 and 2018 , respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2019 and 2018 were settlement charges of $955 thousand and $212 thousand , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $16.3 million and $19.7 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 and 2018 were settlement charges of $4.6 million and $7 million , respectively, related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $67 $38 $69 $5 $119 2018 $114 $42 $73 $20 $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $211 $122 $257 $16 $365 2018 $369 $138 $230 $62 $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $4,675 $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975 12,681 Expected return on assets (9,562 ) (10,373 ) Amortization of prior service credit (8,844 ) (9,251 ) Amortization of net loss 358 3,432 Net other postretirement benefit cost (income) ($1,398 ) $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $14,025 $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925 38,043 Expected return on assets (28,686 ) (31,119 ) Amortization of prior service credit (26,532 ) (27,753 ) Amortization of net loss 1,074 10,296 Net other postretirement benefit cost (income) ($4,194 ) $9,813 The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $591 $1,160 $262 $92 $236 $243 Interest cost on APBO 1,807 2,666 670 395 854 476 Expected return on assets (3,991 ) — (1,199 ) (1,237 ) (2,276 ) (697 ) Amortization of prior service credit (1,238 ) (1,837 ) (439 ) (171 ) (561 ) (363 ) Amortization of net (gain) loss 144 (174 ) 181 58 121 89 Net other postretirement benefit cost (income) ($2,687 ) $1,815 ($525 ) ($863 ) ($1,626 ) ($252 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of net loss 289 388 377 34 206 233 Net other postretirement benefit cost (income) ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,773 $3,480 $786 $276 $708 $729 Interest cost on APBO 5,421 7,998 2,010 1,185 2,562 1,428 Expected return on assets (11,973 ) — (3,597 ) (3,711 ) (6,828 ) (2,091 ) Amortization of prior service credit (3,714 ) (5,511 ) (1,317 ) (513 ) (1,683 ) (1,089 ) Amortization of net (gain) loss 432 (522 ) 543 174 363 267 Net other postretirement benefit cost (income) ($8,061 ) $5,445 ($1,575 ) ($2,589 ) ($4,878 ) ($756 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of net loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost (income) ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 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 third quarters of 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,375 ($50 ) $5,325 Amortization of net gain (loss) (20,686 ) 308 (541 ) (20,919 ) Settlement loss (16,257 ) — (373 ) (16,630 ) ($36,943 ) $5,683 ($964 ) ($32,224 ) Entergy Louisiana Amortization of prior service credit $— $1,837 $— $1,837 Amortization of net gain (loss) (699 ) 174 (1 ) (526 ) ($699 ) $2,011 ($1 ) $1,311 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($297 ) $16,786 ($211 ) $16,278 Amortization of net loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of net loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019. As of September 30, 2019 , Entergy had contributed $123.1 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 2019 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2019 pension contributions $27,112 $26,451 $7,701 $1,800 $1,645 $8,285 Pension contributions made through September 2019 $18,222 $18,272 $5,186 $1,237 $1,192 $5,631 Remaining estimated pension contributions to be made in 2019 $8,890 $8,179 $2,515 $563 $453 $2,654
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 third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,553 $38,752 Interest cost on projected benefit obligation 73,261 66,854 Expected return on assets (103,751 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 60,395 68,526 Settlement charges 16,291 — Net pension costs $79,749 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $100,766 $116,256 Interest cost on projected benefit obligation 221,114 200,562 Expected return on assets (311,494 ) (331,605 ) Amortization of prior service cost — 297 Amortization of net loss 177,233 205,578 Settlement charges 17,591 — Net pension costs $205,210 $191,088 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,260 $7,284 $1,629 $568 $1,350 $1,549 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,873 3,613 3,364 Expected return on assets (20,177 ) (22,651 ) (5,969 ) (2,696 ) (5,862 ) (4,678 ) Amortization of net loss 11,840 11,643 3,104 1,529 2,334 2,850 Net pension cost $11,098 $12,158 $2,832 $1,274 $1,435 $3,085 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projected benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of net loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,782 $21,852 $4,887 $1,706 $4,050 $4,649 Interest cost on projected benefit obligation 42,525 47,646 12,204 5,621 10,837 10,091 Expected return on assets (60,529 ) (67,955 ) (17,905 ) (8,089 ) (17,586 ) (14,032 ) Amortization of net loss 35,522 34,929 9,313 4,588 7,002 8,550 Net pension cost $33,300 $36,472 $8,499 $3,826 $4,303 $9,258 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projected benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of net loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.2 million in pension cost for its non-qualified pension plans in the third quarters of 2019 and 2018 , respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2019 and 2018 were settlement charges of $955 thousand and $212 thousand , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $16.3 million and $19.7 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 and 2018 were settlement charges of $4.6 million and $7 million , respectively, related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $67 $38 $69 $5 $119 2018 $114 $42 $73 $20 $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $211 $122 $257 $16 $365 2018 $369 $138 $230 $62 $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $4,675 $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975 12,681 Expected return on assets (9,562 ) (10,373 ) Amortization of prior service credit (8,844 ) (9,251 ) Amortization of net loss 358 3,432 Net other postretirement benefit cost (income) ($1,398 ) $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $14,025 $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925 38,043 Expected return on assets (28,686 ) (31,119 ) Amortization of prior service credit (26,532 ) (27,753 ) Amortization of net loss 1,074 10,296 Net other postretirement benefit cost (income) ($4,194 ) $9,813 The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $591 $1,160 $262 $92 $236 $243 Interest cost on APBO 1,807 2,666 670 395 854 476 Expected return on assets (3,991 ) — (1,199 ) (1,237 ) (2,276 ) (697 ) Amortization of prior service credit (1,238 ) (1,837 ) (439 ) (171 ) (561 ) (363 ) Amortization of net (gain) loss 144 (174 ) 181 58 121 89 Net other postretirement benefit cost (income) ($2,687 ) $1,815 ($525 ) ($863 ) ($1,626 ) ($252 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of net loss 289 388 377 34 206 233 Net other postretirement benefit cost (income) ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,773 $3,480 $786 $276 $708 $729 Interest cost on APBO 5,421 7,998 2,010 1,185 2,562 1,428 Expected return on assets (11,973 ) — (3,597 ) (3,711 ) (6,828 ) (2,091 ) Amortization of prior service credit (3,714 ) (5,511 ) (1,317 ) (513 ) (1,683 ) (1,089 ) Amortization of net (gain) loss 432 (522 ) 543 174 363 267 Net other postretirement benefit cost (income) ($8,061 ) $5,445 ($1,575 ) ($2,589 ) ($4,878 ) ($756 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of net loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost (income) ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 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 third quarters of 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,375 ($50 ) $5,325 Amortization of net gain (loss) (20,686 ) 308 (541 ) (20,919 ) Settlement loss (16,257 ) — (373 ) (16,630 ) ($36,943 ) $5,683 ($964 ) ($32,224 ) Entergy Louisiana Amortization of prior service credit $— $1,837 $— $1,837 Amortization of net gain (loss) (699 ) 174 (1 ) (526 ) ($699 ) $2,011 ($1 ) $1,311 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($297 ) $16,786 ($211 ) $16,278 Amortization of net loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of net loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019. As of September 30, 2019 , Entergy had contributed $123.1 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 2019 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2019 pension contributions $27,112 $26,451 $7,701 $1,800 $1,645 $8,285 Pension contributions made through September 2019 $18,222 $18,272 $5,186 $1,237 $1,192 $5,631 Remaining estimated pension contributions to be made in 2019 $8,890 $8,179 $2,515 $563 $453 $2,654
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 third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,553 $38,752 Interest cost on projected benefit obligation 73,261 66,854 Expected return on assets (103,751 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 60,395 68,526 Settlement charges 16,291 — Net pension costs $79,749 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $100,766 $116,256 Interest cost on projected benefit obligation 221,114 200,562 Expected return on assets (311,494 ) (331,605 ) Amortization of prior service cost — 297 Amortization of net loss 177,233 205,578 Settlement charges 17,591 — Net pension costs $205,210 $191,088 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,260 $7,284 $1,629 $568 $1,350 $1,549 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,873 3,613 3,364 Expected return on assets (20,177 ) (22,651 ) (5,969 ) (2,696 ) (5,862 ) (4,678 ) Amortization of net loss 11,840 11,643 3,104 1,529 2,334 2,850 Net pension cost $11,098 $12,158 $2,832 $1,274 $1,435 $3,085 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projected benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of net loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,782 $21,852 $4,887 $1,706 $4,050 $4,649 Interest cost on projected benefit obligation 42,525 47,646 12,204 5,621 10,837 10,091 Expected return on assets (60,529 ) (67,955 ) (17,905 ) (8,089 ) (17,586 ) (14,032 ) Amortization of net loss 35,522 34,929 9,313 4,588 7,002 8,550 Net pension cost $33,300 $36,472 $8,499 $3,826 $4,303 $9,258 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projected benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of net loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.2 million in pension cost for its non-qualified pension plans in the third quarters of 2019 and 2018 , respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2019 and 2018 were settlement charges of $955 thousand and $212 thousand , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $16.3 million and $19.7 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 and 2018 were settlement charges of $4.6 million and $7 million , respectively, related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $67 $38 $69 $5 $119 2018 $114 $42 $73 $20 $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $211 $122 $257 $16 $365 2018 $369 $138 $230 $62 $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $4,675 $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975 12,681 Expected return on assets (9,562 ) (10,373 ) Amortization of prior service credit (8,844 ) (9,251 ) Amortization of net loss 358 3,432 Net other postretirement benefit cost (income) ($1,398 ) $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $14,025 $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925 38,043 Expected return on assets (28,686 ) (31,119 ) Amortization of prior service credit (26,532 ) (27,753 ) Amortization of net loss 1,074 10,296 Net other postretirement benefit cost (income) ($4,194 ) $9,813 The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $591 $1,160 $262 $92 $236 $243 Interest cost on APBO 1,807 2,666 670 395 854 476 Expected return on assets (3,991 ) — (1,199 ) (1,237 ) (2,276 ) (697 ) Amortization of prior service credit (1,238 ) (1,837 ) (439 ) (171 ) (561 ) (363 ) Amortization of net (gain) loss 144 (174 ) 181 58 121 89 Net other postretirement benefit cost (income) ($2,687 ) $1,815 ($525 ) ($863 ) ($1,626 ) ($252 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of net loss 289 388 377 34 206 233 Net other postretirement benefit cost (income) ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,773 $3,480 $786 $276 $708 $729 Interest cost on APBO 5,421 7,998 2,010 1,185 2,562 1,428 Expected return on assets (11,973 ) — (3,597 ) (3,711 ) (6,828 ) (2,091 ) Amortization of prior service credit (3,714 ) (5,511 ) (1,317 ) (513 ) (1,683 ) (1,089 ) Amortization of net (gain) loss 432 (522 ) 543 174 363 267 Net other postretirement benefit cost (income) ($8,061 ) $5,445 ($1,575 ) ($2,589 ) ($4,878 ) ($756 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of net loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost (income) ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 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 third quarters of 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,375 ($50 ) $5,325 Amortization of net gain (loss) (20,686 ) 308 (541 ) (20,919 ) Settlement loss (16,257 ) — (373 ) (16,630 ) ($36,943 ) $5,683 ($964 ) ($32,224 ) Entergy Louisiana Amortization of prior service credit $— $1,837 $— $1,837 Amortization of net gain (loss) (699 ) 174 (1 ) (526 ) ($699 ) $2,011 ($1 ) $1,311 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($297 ) $16,786 ($211 ) $16,278 Amortization of net loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of net loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019. As of September 30, 2019 , Entergy had contributed $123.1 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 2019 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2019 pension contributions $27,112 $26,451 $7,701 $1,800 $1,645 $8,285 Pension contributions made through September 2019 $18,222 $18,272 $5,186 $1,237 $1,192 $5,631 Remaining estimated pension contributions to be made in 2019 $8,890 $8,179 $2,515 $563 $453 $2,654
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 third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,553 $38,752 Interest cost on projected benefit obligation 73,261 66,854 Expected return on assets (103,751 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 60,395 68,526 Settlement charges 16,291 — Net pension costs $79,749 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $100,766 $116,256 Interest cost on projected benefit obligation 221,114 200,562 Expected return on assets (311,494 ) (331,605 ) Amortization of prior service cost — 297 Amortization of net loss 177,233 205,578 Settlement charges 17,591 — Net pension costs $205,210 $191,088 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,260 $7,284 $1,629 $568 $1,350 $1,549 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,873 3,613 3,364 Expected return on assets (20,177 ) (22,651 ) (5,969 ) (2,696 ) (5,862 ) (4,678 ) Amortization of net loss 11,840 11,643 3,104 1,529 2,334 2,850 Net pension cost $11,098 $12,158 $2,832 $1,274 $1,435 $3,085 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projected benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of net loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,782 $21,852 $4,887 $1,706 $4,050 $4,649 Interest cost on projected benefit obligation 42,525 47,646 12,204 5,621 10,837 10,091 Expected return on assets (60,529 ) (67,955 ) (17,905 ) (8,089 ) (17,586 ) (14,032 ) Amortization of net loss 35,522 34,929 9,313 4,588 7,002 8,550 Net pension cost $33,300 $36,472 $8,499 $3,826 $4,303 $9,258 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projected benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of net loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.2 million in pension cost for its non-qualified pension plans in the third quarters of 2019 and 2018 , respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2019 and 2018 were settlement charges of $955 thousand and $212 thousand , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $16.3 million and $19.7 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 and 2018 were settlement charges of $4.6 million and $7 million , respectively, related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $67 $38 $69 $5 $119 2018 $114 $42 $73 $20 $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $211 $122 $257 $16 $365 2018 $369 $138 $230 $62 $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $4,675 $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975 12,681 Expected return on assets (9,562 ) (10,373 ) Amortization of prior service credit (8,844 ) (9,251 ) Amortization of net loss 358 3,432 Net other postretirement benefit cost (income) ($1,398 ) $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $14,025 $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925 38,043 Expected return on assets (28,686 ) (31,119 ) Amortization of prior service credit (26,532 ) (27,753 ) Amortization of net loss 1,074 10,296 Net other postretirement benefit cost (income) ($4,194 ) $9,813 The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $591 $1,160 $262 $92 $236 $243 Interest cost on APBO 1,807 2,666 670 395 854 476 Expected return on assets (3,991 ) — (1,199 ) (1,237 ) (2,276 ) (697 ) Amortization of prior service credit (1,238 ) (1,837 ) (439 ) (171 ) (561 ) (363 ) Amortization of net (gain) loss 144 (174 ) 181 58 121 89 Net other postretirement benefit cost (income) ($2,687 ) $1,815 ($525 ) ($863 ) ($1,626 ) ($252 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of net loss 289 388 377 34 206 233 Net other postretirement benefit cost (income) ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,773 $3,480 $786 $276 $708 $729 Interest cost on APBO 5,421 7,998 2,010 1,185 2,562 1,428 Expected return on assets (11,973 ) — (3,597 ) (3,711 ) (6,828 ) (2,091 ) Amortization of prior service credit (3,714 ) (5,511 ) (1,317 ) (513 ) (1,683 ) (1,089 ) Amortization of net (gain) loss 432 (522 ) 543 174 363 267 Net other postretirement benefit cost (income) ($8,061 ) $5,445 ($1,575 ) ($2,589 ) ($4,878 ) ($756 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of net loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost (income) ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 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 third quarters of 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,375 ($50 ) $5,325 Amortization of net gain (loss) (20,686 ) 308 (541 ) (20,919 ) Settlement loss (16,257 ) — (373 ) (16,630 ) ($36,943 ) $5,683 ($964 ) ($32,224 ) Entergy Louisiana Amortization of prior service credit $— $1,837 $— $1,837 Amortization of net gain (loss) (699 ) 174 (1 ) (526 ) ($699 ) $2,011 ($1 ) $1,311 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($297 ) $16,786 ($211 ) $16,278 Amortization of net loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of net loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019. As of September 30, 2019 , Entergy had contributed $123.1 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 2019 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2019 pension contributions $27,112 $26,451 $7,701 $1,800 $1,645 $8,285 Pension contributions made through September 2019 $18,222 $18,272 $5,186 $1,237 $1,192 $5,631 Remaining estimated pension contributions to be made in 2019 $8,890 $8,179 $2,515 $563 $453 $2,654

Business Segment Information

Business Segment Information	9 Months Ended
	Sep. 30, 2019
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of September 30, 2019 are 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 third quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,840,222 $300,363 $9 ($19 ) $3,140,575 Income taxes $71,698 ($30,855 ) ($11,642 ) $— $29,201 Consolidated net income (loss) $581,964 ($140,501 ) ($40,105 ) ($31,899 ) $369,459 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $7,392,641 $1,023,757 $11 ($42 ) $8,416,367 Income taxes $81,283 $25,763 ($33,616 ) $— $73,430 Consolidated net income (loss) $1,150,863 ($68,804 ) ($117,725 ) ($95,695 ) $868,639 Total assets as of September 30, 2019 $48,348,371 $4,122,007 $501,983 ($2,466,093 ) $50,506,268 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of December 31, 2018 $44,777,167 $5,459,275 $733,366 ($2,694,742 ) $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. 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 the remaining 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 third quarters of 2019 and 2018 were comprised of the following: 2019 2018 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $181 $14 $195 $143 $14 $157 Restructuring costs accrued 14 — 14 43 — 43 Cash paid out 86 — 86 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following: 2019 2018 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, $179 $14 $193 $83 $14 $97 Restructuring costs accrued 70 — 70 103 — 103 Cash paid out 140 — 140 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 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 $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 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 Corporation Entergy’s reportable segments as of September 30, 2019 are 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 third quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,840,222 $300,363 $9 ($19 ) $3,140,575 Income taxes $71,698 ($30,855 ) ($11,642 ) $— $29,201 Consolidated net income (loss) $581,964 ($140,501 ) ($40,105 ) ($31,899 ) $369,459 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $7,392,641 $1,023,757 $11 ($42 ) $8,416,367 Income taxes $81,283 $25,763 ($33,616 ) $— $73,430 Consolidated net income (loss) $1,150,863 ($68,804 ) ($117,725 ) ($95,695 ) $868,639 Total assets as of September 30, 2019 $48,348,371 $4,122,007 $501,983 ($2,466,093 ) $50,506,268 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of December 31, 2018 $44,777,167 $5,459,275 $733,366 ($2,694,742 ) $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. 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 the remaining 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 third quarters of 2019 and 2018 were comprised of the following: 2019 2018 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $181 $14 $195 $143 $14 $157 Restructuring costs accrued 14 — 14 43 — 43 Cash paid out 86 — 86 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following: 2019 2018 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, $179 $14 $193 $83 $14 $97 Restructuring costs accrued 70 — 70 103 — 103 Cash paid out 140 — 140 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 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 $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 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 Corporation Entergy’s reportable segments as of September 30, 2019 are 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 third quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,840,222 $300,363 $9 ($19 ) $3,140,575 Income taxes $71,698 ($30,855 ) ($11,642 ) $— $29,201 Consolidated net income (loss) $581,964 ($140,501 ) ($40,105 ) ($31,899 ) $369,459 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $7,392,641 $1,023,757 $11 ($42 ) $8,416,367 Income taxes $81,283 $25,763 ($33,616 ) $— $73,430 Consolidated net income (loss) $1,150,863 ($68,804 ) ($117,725 ) ($95,695 ) $868,639 Total assets as of September 30, 2019 $48,348,371 $4,122,007 $501,983 ($2,466,093 ) $50,506,268 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of December 31, 2018 $44,777,167 $5,459,275 $733,366 ($2,694,742 ) $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. 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 the remaining 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 third quarters of 2019 and 2018 were comprised of the following: 2019 2018 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $181 $14 $195 $143 $14 $157 Restructuring costs accrued 14 — 14 43 — 43 Cash paid out 86 — 86 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following: 2019 2018 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, $179 $14 $193 $83 $14 $97 Restructuring costs accrued 70 — 70 103 — 103 Cash paid out 140 — 140 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 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 $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 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 Corporation Entergy’s reportable segments as of September 30, 2019 are 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 third quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,840,222 $300,363 $9 ($19 ) $3,140,575 Income taxes $71,698 ($30,855 ) ($11,642 ) $— $29,201 Consolidated net income (loss) $581,964 ($140,501 ) ($40,105 ) ($31,899 ) $369,459 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $7,392,641 $1,023,757 $11 ($42 ) $8,416,367 Income taxes $81,283 $25,763 ($33,616 ) $— $73,430 Consolidated net income (loss) $1,150,863 ($68,804 ) ($117,725 ) ($95,695 ) $868,639 Total assets as of September 30, 2019 $48,348,371 $4,122,007 $501,983 ($2,466,093 ) $50,506,268 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of December 31, 2018 $44,777,167 $5,459,275 $733,366 ($2,694,742 ) $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. 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 the remaining 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 third quarters of 2019 and 2018 were comprised of the following: 2019 2018 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $181 $14 $195 $143 $14 $157 Restructuring costs accrued 14 — 14 43 — 43 Cash paid out 86 — 86 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following: 2019 2018 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, $179 $14 $193 $83 $14 $97 Restructuring costs accrued 70 — 70 103 — 103 Cash paid out 140 — 140 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 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 $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 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 Corporation Entergy’s reportable segments as of September 30, 2019 are 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 third quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,840,222 $300,363 $9 ($19 ) $3,140,575 Income taxes $71,698 ($30,855 ) ($11,642 ) $— $29,201 Consolidated net income (loss) $581,964 ($140,501 ) ($40,105 ) ($31,899 ) $369,459 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $7,392,641 $1,023,757 $11 ($42 ) $8,416,367 Income taxes $81,283 $25,763 ($33,616 ) $— $73,430 Consolidated net income (loss) $1,150,863 ($68,804 ) ($117,725 ) ($95,695 ) $868,639 Total assets as of September 30, 2019 $48,348,371 $4,122,007 $501,983 ($2,466,093 ) $50,506,268 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of December 31, 2018 $44,777,167 $5,459,275 $733,366 ($2,694,742 ) $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. 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 the remaining 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 third quarters of 2019 and 2018 were comprised of the following: 2019 2018 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $181 $14 $195 $143 $14 $157 Restructuring costs accrued 14 — 14 43 — 43 Cash paid out 86 — 86 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following: 2019 2018 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, $179 $14 $193 $83 $14 $97 Restructuring costs accrued 70 — 70 103 — 103 Cash paid out 140 — 140 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 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 $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 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 Corporation Entergy’s reportable segments as of September 30, 2019 are 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 third quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,840,222 $300,363 $9 ($19 ) $3,140,575 Income taxes $71,698 ($30,855 ) ($11,642 ) $— $29,201 Consolidated net income (loss) $581,964 ($140,501 ) ($40,105 ) ($31,899 ) $369,459 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $7,392,641 $1,023,757 $11 ($42 ) $8,416,367 Income taxes $81,283 $25,763 ($33,616 ) $— $73,430 Consolidated net income (loss) $1,150,863 ($68,804 ) ($117,725 ) ($95,695 ) $868,639 Total assets as of September 30, 2019 $48,348,371 $4,122,007 $501,983 ($2,466,093 ) $50,506,268 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of December 31, 2018 $44,777,167 $5,459,275 $733,366 ($2,694,742 ) $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. 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 the remaining 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 third quarters of 2019 and 2018 were comprised of the following: 2019 2018 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $181 $14 $195 $143 $14 $157 Restructuring costs accrued 14 — 14 43 — 43 Cash paid out 86 — 86 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following: 2019 2018 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, $179 $14 $193 $83 $14 $97 Restructuring costs accrued 70 — 70 103 — 103 Cash paid out 140 — 140 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 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 $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 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 Corporation Entergy’s reportable segments as of September 30, 2019 are 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 third quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,840,222 $300,363 $9 ($19 ) $3,140,575 Income taxes $71,698 ($30,855 ) ($11,642 ) $— $29,201 Consolidated net income (loss) $581,964 ($140,501 ) ($40,105 ) ($31,899 ) $369,459 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $7,392,641 $1,023,757 $11 ($42 ) $8,416,367 Income taxes $81,283 $25,763 ($33,616 ) $— $73,430 Consolidated net income (loss) $1,150,863 ($68,804 ) ($117,725 ) ($95,695 ) $868,639 Total assets as of September 30, 2019 $48,348,371 $4,122,007 $501,983 ($2,466,093 ) $50,506,268 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of December 31, 2018 $44,777,167 $5,459,275 $733,366 ($2,694,742 ) $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. 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 the remaining 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 third quarters of 2019 and 2018 were comprised of the following: 2019 2018 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $181 $14 $195 $143 $14 $157 Restructuring costs accrued 14 — 14 43 — 43 Cash paid out 86 — 86 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following: 2019 2018 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, $179 $14 $193 $83 $14 $97 Restructuring costs accrued 70 — 70 103 — 103 Cash paid out 140 — 140 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 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 $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 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	9 Months Ended
	Sep. 30, 2019
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 enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. 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 enters 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 settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2019 is approximately 1.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2019 , of which approximately 72% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2019 is 6.1 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow 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. As of September 30, 2019 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $13 million in cash collateral were required to be posted by the Entergy subsidiary to its counterparties and $2 million in cash and $48 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2018 , derivative contracts with six counterparties were in a liability position (approximately $34 million total). In addition to the corporate guarantee, $19 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. 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. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of September 30, 2019 is 4.5 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of September 30, 2019 is 6 months each for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2019 is 40,346,000 MMBtu for Entergy, including 32,880,000 MMBtu for Entergy Louisiana, 6,210,000 MMBtu for Entergy Mississippi, and 1,256,000 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 2019, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2019 through May 31, 2020. Financial transmission rights are derivative instruments which 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 September 30, 2019 is 79,459 GWh for Entergy, including 17,898 GWh for Entergy Arkansas, 36,474 GWh for Entergy Louisiana, 10,087 GWh for Entergy Mississippi, 3,751 GWh for Entergy New Orleans, and 10,931 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi as of September 30, 2019 and Entergy Mississippi and Entergy Texas as of December 31, 2018. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $35 ($5) $30 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $14 ($2) $12 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $5 ($5) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($3) $6 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $17 ($1) $16 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $4 $— $4 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $32 ($32) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $7 ($7) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $54 ($33) $21 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $20 ($7) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $4 ($2) $2 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $2 $— $2 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $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 $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2019 Electricity swaps and options ($7) Competitive businesses operating revenues $19 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2019 Electricity swaps and options $145 Competitive businesses operating revenues $76 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively Prior to the adoption of ASU 2017-12, Entergy measured its hedges for ineffectiveness. Any ineffectiveness was recognized in earnings during the period. The ineffective portion of cash flow hedges was recorded in competitive businesses operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 was ($3.1) million . The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 was ($5.2) million . Based on market prices as of September 30, 2019 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $42 million of net unrealized losses. Approximately $30 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. 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 September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights $— Purchased power expense (b) $25 Electricity swaps and options $— (c) Competitive business operating revenues $1 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 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 nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps and options $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options $— (c) Competitive business operating revenues $4 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— (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) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.1 $— $0.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1.0 $— $1.0 Entergy Louisiana Financial transmission rights Prepayments and other $4.0 ($0.1) $3.9 Entergy Arkansas Financial transmission rights Prepayments and other $9.1 $— $9.1 Entergy Louisiana Financial transmission rights Prepayments and other $1.5 $— $1.5 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($0.4) $1.3 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $2.2 $— $2.2 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.4 $— $1.4 Entergy Louisiana Natural gas swaps Other current liabilities $1.1 $— $1.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.1 $— $0.1 Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $1.6 $— $1.6 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.4 ($0.1) $8.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.3 $— $1.3 Entergy New Orleans Liabilities: Financial transmission rights Other current liabilities $0.9 ($1.4) ($0.5) Entergy Texas Natural gas swaps and options Other current liabilities $1.1 $— $1.1 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 $— $0.1 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 September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 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 September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.3) (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 $3.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $14.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $1.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense ($0.3) (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.5 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($3.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.5) (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 $15.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $40.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $13.6 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (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 Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group 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 Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electrici
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 enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. 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 enters 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 settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2019 is approximately 1.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2019 , of which approximately 72% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2019 is 6.1 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow 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. As of September 30, 2019 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $13 million in cash collateral were required to be posted by the Entergy subsidiary to its counterparties and $2 million in cash and $48 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2018 , derivative contracts with six counterparties were in a liability position (approximately $34 million total). In addition to the corporate guarantee, $19 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. 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. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of September 30, 2019 is 4.5 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of September 30, 2019 is 6 months each for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2019 is 40,346,000 MMBtu for Entergy, including 32,880,000 MMBtu for Entergy Louisiana, 6,210,000 MMBtu for Entergy Mississippi, and 1,256,000 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 2019, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2019 through May 31, 2020. Financial transmission rights are derivative instruments which 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 September 30, 2019 is 79,459 GWh for Entergy, including 17,898 GWh for Entergy Arkansas, 36,474 GWh for Entergy Louisiana, 10,087 GWh for Entergy Mississippi, 3,751 GWh for Entergy New Orleans, and 10,931 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi as of September 30, 2019 and Entergy Mississippi and Entergy Texas as of December 31, 2018. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $35 ($5) $30 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $14 ($2) $12 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $5 ($5) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($3) $6 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $17 ($1) $16 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $4 $— $4 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $32 ($32) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $7 ($7) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $54 ($33) $21 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $20 ($7) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $4 ($2) $2 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $2 $— $2 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $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 $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2019 Electricity swaps and options ($7) Competitive businesses operating revenues $19 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2019 Electricity swaps and options $145 Competitive businesses operating revenues $76 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively Prior to the adoption of ASU 2017-12, Entergy measured its hedges for ineffectiveness. Any ineffectiveness was recognized in earnings during the period. The ineffective portion of cash flow hedges was recorded in competitive businesses operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 was ($3.1) million . The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 was ($5.2) million . Based on market prices as of September 30, 2019 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $42 million of net unrealized losses. Approximately $30 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. 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 September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights $— Purchased power expense (b) $25 Electricity swaps and options $— (c) Competitive business operating revenues $1 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 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 nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps and options $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options $— (c) Competitive business operating revenues $4 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— (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) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.1 $— $0.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1.0 $— $1.0 Entergy Louisiana Financial transmission rights Prepayments and other $4.0 ($0.1) $3.9 Entergy Arkansas Financial transmission rights Prepayments and other $9.1 $— $9.1 Entergy Louisiana Financial transmission rights Prepayments and other $1.5 $— $1.5 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($0.4) $1.3 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $2.2 $— $2.2 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.4 $— $1.4 Entergy Louisiana Natural gas swaps Other current liabilities $1.1 $— $1.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.1 $— $0.1 Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $1.6 $— $1.6 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.4 ($0.1) $8.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.3 $— $1.3 Entergy New Orleans Liabilities: Financial transmission rights Other current liabilities $0.9 ($1.4) ($0.5) Entergy Texas Natural gas swaps and options Other current liabilities $1.1 $— $1.1 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 $— $0.1 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 September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 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 September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.3) (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 $3.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $14.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $1.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense ($0.3) (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.5 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($3.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.5) (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 $15.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $40.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $13.6 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (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 Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group 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 Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electrici
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 enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. 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 enters 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 settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2019 is approximately 1.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2019 , of which approximately 72% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2019 is 6.1 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow 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. As of September 30, 2019 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $13 million in cash collateral were required to be posted by the Entergy subsidiary to its counterparties and $2 million in cash and $48 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2018 , derivative contracts with six counterparties were in a liability position (approximately $34 million total). In addition to the corporate guarantee, $19 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. 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. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of September 30, 2019 is 4.5 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of September 30, 2019 is 6 months each for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2019 is 40,346,000 MMBtu for Entergy, including 32,880,000 MMBtu for Entergy Louisiana, 6,210,000 MMBtu for Entergy Mississippi, and 1,256,000 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 2019, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2019 through May 31, 2020. Financial transmission rights are derivative instruments which 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 September 30, 2019 is 79,459 GWh for Entergy, including 17,898 GWh for Entergy Arkansas, 36,474 GWh for Entergy Louisiana, 10,087 GWh for Entergy Mississippi, 3,751 GWh for Entergy New Orleans, and 10,931 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi as of September 30, 2019 and Entergy Mississippi and Entergy Texas as of December 31, 2018. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $35 ($5) $30 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $14 ($2) $12 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $5 ($5) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($3) $6 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $17 ($1) $16 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $4 $— $4 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $32 ($32) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $7 ($7) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $54 ($33) $21 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $20 ($7) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $4 ($2) $2 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $2 $— $2 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $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 $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2019 Electricity swaps and options ($7) Competitive businesses operating revenues $19 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2019 Electricity swaps and options $145 Competitive businesses operating revenues $76 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively Prior to the adoption of ASU 2017-12, Entergy measured its hedges for ineffectiveness. Any ineffectiveness was recognized in earnings during the period. The ineffective portion of cash flow hedges was recorded in competitive businesses operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 was ($3.1) million . The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 was ($5.2) million . Based on market prices as of September 30, 2019 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $42 million of net unrealized losses. Approximately $30 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. 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 September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights $— Purchased power expense (b) $25 Electricity swaps and options $— (c) Competitive business operating revenues $1 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 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 nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps and options $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options $— (c) Competitive business operating revenues $4 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— (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) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.1 $— $0.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1.0 $— $1.0 Entergy Louisiana Financial transmission rights Prepayments and other $4.0 ($0.1) $3.9 Entergy Arkansas Financial transmission rights Prepayments and other $9.1 $— $9.1 Entergy Louisiana Financial transmission rights Prepayments and other $1.5 $— $1.5 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($0.4) $1.3 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $2.2 $— $2.2 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.4 $— $1.4 Entergy Louisiana Natural gas swaps Other current liabilities $1.1 $— $1.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.1 $— $0.1 Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $1.6 $— $1.6 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.4 ($0.1) $8.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.3 $— $1.3 Entergy New Orleans Liabilities: Financial transmission rights Other current liabilities $0.9 ($1.4) ($0.5) Entergy Texas Natural gas swaps and options Other current liabilities $1.1 $— $1.1 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 $— $0.1 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 September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 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 September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.3) (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 $3.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $14.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $1.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense ($0.3) (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.5 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($3.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.5) (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 $15.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $40.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $13.6 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (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 Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group 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 Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electrici
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 enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. 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 enters 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 settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2019 is approximately 1.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2019 , of which approximately 72% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2019 is 6.1 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow 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. As of September 30, 2019 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $13 million in cash collateral were required to be posted by the Entergy subsidiary to its counterparties and $2 million in cash and $48 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2018 , derivative contracts with six counterparties were in a liability position (approximately $34 million total). In addition to the corporate guarantee, $19 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. 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. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of September 30, 2019 is 4.5 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of September 30, 2019 is 6 months each for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2019 is 40,346,000 MMBtu for Entergy, including 32,880,000 MMBtu for Entergy Louisiana, 6,210,000 MMBtu for Entergy Mississippi, and 1,256,000 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 2019, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2019 through May 31, 2020. Financial transmission rights are derivative instruments which 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 September 30, 2019 is 79,459 GWh for Entergy, including 17,898 GWh for Entergy Arkansas, 36,474 GWh for Entergy Louisiana, 10,087 GWh for Entergy Mississippi, 3,751 GWh for Entergy New Orleans, and 10,931 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi as of September 30, 2019 and Entergy Mississippi and Entergy Texas as of December 31, 2018. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $35 ($5) $30 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $14 ($2) $12 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $5 ($5) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($3) $6 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $17 ($1) $16 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $4 $— $4 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $32 ($32) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $7 ($7) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $54 ($33) $21 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $20 ($7) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $4 ($2) $2 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $2 $— $2 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $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 $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2019 Electricity swaps and options ($7) Competitive businesses operating revenues $19 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2019 Electricity swaps and options $145 Competitive businesses operating revenues $76 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively Prior to the adoption of ASU 2017-12, Entergy measured its hedges for ineffectiveness. Any ineffectiveness was recognized in earnings during the period. The ineffective portion of cash flow hedges was recorded in competitive businesses operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 was ($3.1) million . The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 was ($5.2) million . Based on market prices as of September 30, 2019 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $42 million of net unrealized losses. Approximately $30 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. 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 September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights $— Purchased power expense (b) $25 Electricity swaps and options $— (c) Competitive business operating revenues $1 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 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 nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps and options $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options $— (c) Competitive business operating revenues $4 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— (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) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.1 $— $0.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1.0 $— $1.0 Entergy Louisiana Financial transmission rights Prepayments and other $4.0 ($0.1) $3.9 Entergy Arkansas Financial transmission rights Prepayments and other $9.1 $— $9.1 Entergy Louisiana Financial transmission rights Prepayments and other $1.5 $— $1.5 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($0.4) $1.3 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $2.2 $— $2.2 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.4 $— $1.4 Entergy Louisiana Natural gas swaps Other current liabilities $1.1 $— $1.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.1 $— $0.1 Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $1.6 $— $1.6 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.4 ($0.1) $8.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.3 $— $1.3 Entergy New Orleans Liabilities: Financial transmission rights Other current liabilities $0.9 ($1.4) ($0.5) Entergy Texas Natural gas swaps and options Other current liabilities $1.1 $— $1.1 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 $— $0.1 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 September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 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 September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.3) (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 $3.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $14.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $1.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense ($0.3) (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.5 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($3.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.5) (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 $15.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $40.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $13.6 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (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 Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group 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 Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electrici
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 enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. 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 enters 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 settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2019 is approximately 1.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2019 , of which approximately 72% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2019 is 6.1 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow 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. As of September 30, 2019 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $13 million in cash collateral were required to be posted by the Entergy subsidiary to its counterparties and $2 million in cash and $48 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2018 , derivative contracts with six counterparties were in a liability position (approximately $34 million total). In addition to the corporate guarantee, $19 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. 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. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of September 30, 2019 is 4.5 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of September 30, 2019 is 6 months each for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2019 is 40,346,000 MMBtu for Entergy, including 32,880,000 MMBtu for Entergy Louisiana, 6,210,000 MMBtu for Entergy Mississippi, and 1,256,000 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 2019, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2019 through May 31, 2020. Financial transmission rights are derivative instruments which 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 September 30, 2019 is 79,459 GWh for Entergy, including 17,898 GWh for Entergy Arkansas, 36,474 GWh for Entergy Louisiana, 10,087 GWh for Entergy Mississippi, 3,751 GWh for Entergy New Orleans, and 10,931 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi as of September 30, 2019 and Entergy Mississippi and Entergy Texas as of December 31, 2018. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $35 ($5) $30 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $14 ($2) $12 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $5 ($5) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($3) $6 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $17 ($1) $16 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $4 $— $4 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $32 ($32) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $7 ($7) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $54 ($33) $21 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $20 ($7) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $4 ($2) $2 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $2 $— $2 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $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 $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2019 Electricity swaps and options ($7) Competitive businesses operating revenues $19 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2019 Electricity swaps and options $145 Competitive businesses operating revenues $76 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively Prior to the adoption of ASU 2017-12, Entergy measured its hedges for ineffectiveness. Any ineffectiveness was recognized in earnings during the period. The ineffective portion of cash flow hedges was recorded in competitive businesses operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 was ($3.1) million . The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 was ($5.2) million . Based on market prices as of September 30, 2019 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $42 million of net unrealized losses. Approximately $30 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. 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 September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights $— Purchased power expense (b) $25 Electricity swaps and options $— (c) Competitive business operating revenues $1 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 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 nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps and options $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options $— (c) Competitive business operating revenues $4 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— (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) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.1 $— $0.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1.0 $— $1.0 Entergy Louisiana Financial transmission rights Prepayments and other $4.0 ($0.1) $3.9 Entergy Arkansas Financial transmission rights Prepayments and other $9.1 $— $9.1 Entergy Louisiana Financial transmission rights Prepayments and other $1.5 $— $1.5 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($0.4) $1.3 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $2.2 $— $2.2 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.4 $— $1.4 Entergy Louisiana Natural gas swaps Other current liabilities $1.1 $— $1.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.1 $— $0.1 Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $1.6 $— $1.6 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.4 ($0.1) $8.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.3 $— $1.3 Entergy New Orleans Liabilities: Financial transmission rights Other current liabilities $0.9 ($1.4) ($0.5) Entergy Texas Natural gas swaps and options Other current liabilities $1.1 $— $1.1 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 $— $0.1 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 September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 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 September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.3) (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 $3.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $14.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $1.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense ($0.3) (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.5 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($3.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.5) (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 $15.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $40.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $13.6 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (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 Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group 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 Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electrici
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 enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. 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 enters 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 settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2019 is approximately 1.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2019 , of which approximately 72% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2019 is 6.1 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow 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. As of September 30, 2019 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $13 million in cash collateral were required to be posted by the Entergy subsidiary to its counterparties and $2 million in cash and $48 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2018 , derivative contracts with six counterparties were in a liability position (approximately $34 million total). In addition to the corporate guarantee, $19 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. 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. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of September 30, 2019 is 4.5 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of September 30, 2019 is 6 months each for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2019 is 40,346,000 MMBtu for Entergy, including 32,880,000 MMBtu for Entergy Louisiana, 6,210,000 MMBtu for Entergy Mississippi, and 1,256,000 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 2019, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2019 through May 31, 2020. Financial transmission rights are derivative instruments which 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 September 30, 2019 is 79,459 GWh for Entergy, including 17,898 GWh for Entergy Arkansas, 36,474 GWh for Entergy Louisiana, 10,087 GWh for Entergy Mississippi, 3,751 GWh for Entergy New Orleans, and 10,931 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi as of September 30, 2019 and Entergy Mississippi and Entergy Texas as of December 31, 2018. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $35 ($5) $30 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $14 ($2) $12 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $5 ($5) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($3) $6 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $17 ($1) $16 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $4 $— $4 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $32 ($32) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $7 ($7) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $54 ($33) $21 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $20 ($7) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $4 ($2) $2 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $2 $— $2 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $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 $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2019 Electricity swaps and options ($7) Competitive businesses operating revenues $19 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2019 Electricity swaps and options $145 Competitive businesses operating revenues $76 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively Prior to the adoption of ASU 2017-12, Entergy measured its hedges for ineffectiveness. Any ineffectiveness was recognized in earnings during the period. The ineffective portion of cash flow hedges was recorded in competitive businesses operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 was ($3.1) million . The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 was ($5.2) million . Based on market prices as of September 30, 2019 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $42 million of net unrealized losses. Approximately $30 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. 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 September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights $— Purchased power expense (b) $25 Electricity swaps and options $— (c) Competitive business operating revenues $1 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 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 nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps and options $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options $— (c) Competitive business operating revenues $4 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— (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) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.1 $— $0.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1.0 $— $1.0 Entergy Louisiana Financial transmission rights Prepayments and other $4.0 ($0.1) $3.9 Entergy Arkansas Financial transmission rights Prepayments and other $9.1 $— $9.1 Entergy Louisiana Financial transmission rights Prepayments and other $1.5 $— $1.5 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($0.4) $1.3 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $2.2 $— $2.2 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.4 $— $1.4 Entergy Louisiana Natural gas swaps Other current liabilities $1.1 $— $1.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.1 $— $0.1 Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $1.6 $— $1.6 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.4 ($0.1) $8.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.3 $— $1.3 Entergy New Orleans Liabilities: Financial transmission rights Other current liabilities $0.9 ($1.4) ($0.5) Entergy Texas Natural gas swaps and options Other current liabilities $1.1 $— $1.1 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 $— $0.1 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 September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 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 September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.3) (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 $3.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $14.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $1.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense ($0.3) (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.5 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($3.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.5) (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 $15.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $40.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $13.6 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (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 Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group 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 Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electrici
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 enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. 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 enters 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 settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2019 is approximately 1.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2019 , of which approximately 72% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2019 is 6.1 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow 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. As of September 30, 2019 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $13 million in cash collateral were required to be posted by the Entergy subsidiary to its counterparties and $2 million in cash and $48 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2018 , derivative contracts with six counterparties were in a liability position (approximately $34 million total). In addition to the corporate guarantee, $19 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. 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. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of September 30, 2019 is 4.5 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of September 30, 2019 is 6 months each for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2019 is 40,346,000 MMBtu for Entergy, including 32,880,000 MMBtu for Entergy Louisiana, 6,210,000 MMBtu for Entergy Mississippi, and 1,256,000 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 2019, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2019 through May 31, 2020. Financial transmission rights are derivative instruments which 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 September 30, 2019 is 79,459 GWh for Entergy, including 17,898 GWh for Entergy Arkansas, 36,474 GWh for Entergy Louisiana, 10,087 GWh for Entergy Mississippi, 3,751 GWh for Entergy New Orleans, and 10,931 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi as of September 30, 2019 and Entergy Mississippi and Entergy Texas as of December 31, 2018. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $35 ($5) $30 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $14 ($2) $12 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $5 ($5) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($3) $6 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $17 ($1) $16 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $4 $— $4 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $32 ($32) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $7 ($7) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $54 ($33) $21 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $20 ($7) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $4 ($2) $2 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $2 $— $2 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $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 $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2019 Electricity swaps and options ($7) Competitive businesses operating revenues $19 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2019 Electricity swaps and options $145 Competitive businesses operating revenues $76 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively Prior to the adoption of ASU 2017-12, Entergy measured its hedges for ineffectiveness. Any ineffectiveness was recognized in earnings during the period. The ineffective portion of cash flow hedges was recorded in competitive businesses operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 was ($3.1) million . The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 was ($5.2) million . Based on market prices as of September 30, 2019 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $42 million of net unrealized losses. Approximately $30 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. 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 September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights $— Purchased power expense (b) $25 Electricity swaps and options $— (c) Competitive business operating revenues $1 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 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 nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps and options $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options $— (c) Competitive business operating revenues $4 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— (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) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.1 $— $0.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1.0 $— $1.0 Entergy Louisiana Financial transmission rights Prepayments and other $4.0 ($0.1) $3.9 Entergy Arkansas Financial transmission rights Prepayments and other $9.1 $— $9.1 Entergy Louisiana Financial transmission rights Prepayments and other $1.5 $— $1.5 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($0.4) $1.3 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $2.2 $— $2.2 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.4 $— $1.4 Entergy Louisiana Natural gas swaps Other current liabilities $1.1 $— $1.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.1 $— $0.1 Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $1.6 $— $1.6 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.4 ($0.1) $8.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.3 $— $1.3 Entergy New Orleans Liabilities: Financial transmission rights Other current liabilities $0.9 ($1.4) ($0.5) Entergy Texas Natural gas swaps and options Other current liabilities $1.1 $— $1.1 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 $— $0.1 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 September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 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 September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.3) (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 $3.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $14.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $1.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense ($0.3) (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.5 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($3.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.5) (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 $15.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $40.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $13.6 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (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 Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group 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 Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electrici

Decommissioning Trust Funds

Decommissioning Trust Funds	9 Months Ended
	Sep. 30, 2019
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, Indian Point 1, Indian Point 2, Indian Point 3, 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 16 to the financial statements herein and Note 14 to the financial statements in the Form 10-K, in January 2019, Entergy completed the transfer of the Vermont Yankee plant to NorthStar. As part of the transaction, Entergy transferred the Vermont Yankee decommissioning trust fund to NorthStar. As of December 31, 2018, the fair value of the decommissioning trust fund was $532 million . As discussed in Note 16 to the financial statements herein, in August 2019, Entergy completed the transfer of the Pilgrim plant to Holtec. As part of the transaction, Entergy transferred the Pilgrim decommissioning trust fund to Holtec. The disposition-date fair value of the decommissioning trust fund was approximately $1,030 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 Indian Point 1, Indian Point 2, Indian Point 3, and Palisades 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 are 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 are recognized in earnings. 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 nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $17 million and $491 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities (a) $2,462 $114 $2 2018 Debt Securities (a) $2,495 $19 $35 (a) Debt securities presented herein do not include the $506 million and $389 million of debt securities held in the wholly-owned registered investment company as of September 30, 2019 and December 31, 2018 , respectively, which are not accounted for as available-for-sale. The unrealized gains/(losses) above are reported before deferred taxes of $16 million as of September 30, 2019 and ($1) million as of December 31, 2018 for debt securities. The amortized cost of available-for-sale debt securities was $2,362 million as of September 30, 2019 and $2,511 million as of December 31, 2018 . As of September 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 3.15% , an average duration of approximately 5.63 years, and an average maturity of approximately 9.02 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $236 $2 More than 12 months 67 — Total $303 $2 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $652 $9 More than 12 months 782 26 Total $1,434 $35 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $165 $199 1 year - 5 years 870 1,066 5 years - 10 years 636 544 10 years - 15 years 89 77 15 years - 20 years 98 78 20 years+ 604 531 Total $2,462 $2,495 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $407 million and $2,377 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $11 million and $4 million , respectively, and gross losses of $0.4 million and $15 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $1,133 million and $4,178 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $20 million and $6 million , respectively, and gross losses of $3 million and $37 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of September 30, 2019 are $534 million for Indian Point 1, $676 million for Indian Point 2, $893 million for Indian Point 3, and $492 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2018 are $471 million for Indian Point 1, $598 million for Indian Point 2, $781 million for Indian Point 3, $444 million for Palisades, $1,028 million for Pilgrim, and $532 million for Vermont Yankee. 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $407.7 $11.8 $0.9 2018 Debt Securities $381.3 $0.6 $8.2 The amortized cost of available-for-sale debt securities was $396.8 million as of September 30, 2019 and $389 million as of December 31, 2018 . As of September 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 2.78% , an average duration of approximately 5.57 years, and an average maturity of approximately 8.13 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.6 million and $96.5 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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $51.5 $0.8 More than 12 months 21.0 0.1 Total $72.5 $0.9 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $65.8 $0.5 More than 12 months 231.1 7.7 Total $296.9 $8.2 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $50.3 $32.5 1 year - 5 years 120.4 170.3 5 years - 10 years 144.5 114.0 10 years - 15 years 24.3 10.3 15 years - 20 years 14.2 8.1 20 years+ 54.0 46.1 Total $407.7 $381.3 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $45.5 million and $137.9 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $2 million and $0.01 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2018, gross losses of $0.6 million related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2019 , there were no gross losses. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $78.7 million and $259.3 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $2.1 million and $0.1 million , respectively, and gross losses of $0.1 million and $3 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $593.4 $32.6 $0.3 2018 Debt Securities $532.9 $4.1 $6.0 The amortized cost of available-for-sale debt securities was $561 million as of September 30, 2019 and $534.8 million as of December 31, 2018 . As of September 30, 2019 , the available-for-sale debt securities have an average coupon rate of approximately 3.85% , an average duration of approximately 6.53 years, and an average maturity of approximately 13.11 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $6 million and $137.2 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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $49.3 $0.3 More than 12 months 12.9 — Total $62.2 $0.3 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $170.1 $2.1 More than 12 months 145.8 3.9 Total $315.9 $6.0 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $56.6 $31.1 1 year - 5 years 138.2 130.5 5 years - 10 years 118.4 111.0 10 years - 15 years 34.7 29.0 15 years - 20 years 45.0 37.1 20 years+ 200.5 194.2 Total $593.4 $532.9 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $59.7 million and $773.9 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $2.5 million and $1.9 million , respectively, and gross losses of $29 thousand and $3.6 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $155.4 million and $943.3 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $4.2 million and $2.5 million , respectively, and gross losses of $0.2 million and $4.8 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $395.3 $19.7 $0.1 2018 Debt Securities $364.2 $2.9 $5.8 The amortized cost of available-for-sale debt securities was $375.6 million as of September 30, 2019 and $367.1 million as of December 31, 2018 . As of September 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 3.09% , an average duration of approximately 6.84 years, and an average maturity of approximately 9.88 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.5 million and $91.8 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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $38.8 $0.1 More than 12 months 4.3 — Total $43.1 $0.1 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $89.7 $2.4 More than 12 months 79.8 3.4 Total $169.5 $5.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $11.2 $22.8 1 year - 5 years 187.7 188.0 5 years - 10 years 92.7 73.4 10 years - 15 years 3.0 5.2 15 years - 20 years 5.9 10.2 20 years+ 94.8 64.6 Total $395.3 $364.2 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $108.6 million and $157.8 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $1.7 million and $6.5 thousand , respectively, and gross losses of $0.2 million and $0.3 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $238.4 million and $357.2 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $3.6 million and $0.3 million , respectively, and gross losses of $0.6 million and $4.8 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates the available-for-sale debt securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred. The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three and nine months ended September 30, 2019 and 2018
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, Indian Point 1, Indian Point 2, Indian Point 3, 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 16 to the financial statements herein and Note 14 to the financial statements in the Form 10-K, in January 2019, Entergy completed the transfer of the Vermont Yankee plant to NorthStar. As part of the transaction, Entergy transferred the Vermont Yankee decommissioning trust fund to NorthStar. As of December 31, 2018, the fair value of the decommissioning trust fund was $532 million . As discussed in Note 16 to the financial statements herein, in August 2019, Entergy completed the transfer of the Pilgrim plant to Holtec. As part of the transaction, Entergy transferred the Pilgrim decommissioning trust fund to Holtec. The disposition-date fair value of the decommissioning trust fund was approximately $1,030 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 Indian Point 1, Indian Point 2, Indian Point 3, and Palisades 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 are 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 are recognized in earnings. 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 nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $17 million and $491 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities (a) $2,462 $114 $2 2018 Debt Securities (a) $2,495 $19 $35 (a) Debt securities presented herein do not include the $506 million and $389 million of debt securities held in the wholly-owned registered investment company as of September 30, 2019 and December 31, 2018 , respectively, which are not accounted for as available-for-sale. The unrealized gains/(losses) above are reported before deferred taxes of $16 million as of September 30, 2019 and ($1) million as of December 31, 2018 for debt securities. The amortized cost of available-for-sale debt securities was $2,362 million as of September 30, 2019 and $2,511 million as of December 31, 2018 . As of September 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 3.15% , an average duration of approximately 5.63 years, and an average maturity of approximately 9.02 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $236 $2 More than 12 months 67 — Total $303 $2 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $652 $9 More than 12 months 782 26 Total $1,434 $35 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $165 $199 1 year - 5 years 870 1,066 5 years - 10 years 636 544 10 years - 15 years 89 77 15 years - 20 years 98 78 20 years+ 604 531 Total $2,462 $2,495 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $407 million and $2,377 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $11 million and $4 million , respectively, and gross losses of $0.4 million and $15 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $1,133 million and $4,178 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $20 million and $6 million , respectively, and gross losses of $3 million and $37 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of September 30, 2019 are $534 million for Indian Point 1, $676 million for Indian Point 2, $893 million for Indian Point 3, and $492 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2018 are $471 million for Indian Point 1, $598 million for Indian Point 2, $781 million for Indian Point 3, $444 million for Palisades, $1,028 million for Pilgrim, and $532 million for Vermont Yankee. 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $407.7 $11.8 $0.9 2018 Debt Securities $381.3 $0.6 $8.2 The amortized cost of available-for-sale debt securities was $396.8 million as of September 30, 2019 and $389 million as of December 31, 2018 . As of September 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 2.78% , an average duration of approximately 5.57 years, and an average maturity of approximately 8.13 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.6 million and $96.5 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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $51.5 $0.8 More than 12 months 21.0 0.1 Total $72.5 $0.9 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $65.8 $0.5 More than 12 months 231.1 7.7 Total $296.9 $8.2 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $50.3 $32.5 1 year - 5 years 120.4 170.3 5 years - 10 years 144.5 114.0 10 years - 15 years 24.3 10.3 15 years - 20 years 14.2 8.1 20 years+ 54.0 46.1 Total $407.7 $381.3 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $45.5 million and $137.9 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $2 million and $0.01 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2018, gross losses of $0.6 million related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2019 , there were no gross losses. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $78.7 million and $259.3 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $2.1 million and $0.1 million , respectively, and gross losses of $0.1 million and $3 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $593.4 $32.6 $0.3 2018 Debt Securities $532.9 $4.1 $6.0 The amortized cost of available-for-sale debt securities was $561 million as of September 30, 2019 and $534.8 million as of December 31, 2018 . As of September 30, 2019 , the available-for-sale debt securities have an average coupon rate of approximately 3.85% , an average duration of approximately 6.53 years, and an average maturity of approximately 13.11 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $6 million and $137.2 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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $49.3 $0.3 More than 12 months 12.9 — Total $62.2 $0.3 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $170.1 $2.1 More than 12 months 145.8 3.9 Total $315.9 $6.0 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $56.6 $31.1 1 year - 5 years 138.2 130.5 5 years - 10 years 118.4 111.0 10 years - 15 years 34.7 29.0 15 years - 20 years 45.0 37.1 20 years+ 200.5 194.2 Total $593.4 $532.9 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $59.7 million and $773.9 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $2.5 million and $1.9 million , respectively, and gross losses of $29 thousand and $3.6 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $155.4 million and $943.3 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $4.2 million and $2.5 million , respectively, and gross losses of $0.2 million and $4.8 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $395.3 $19.7 $0.1 2018 Debt Securities $364.2 $2.9 $5.8 The amortized cost of available-for-sale debt securities was $375.6 million as of September 30, 2019 and $367.1 million as of December 31, 2018 . As of September 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 3.09% , an average duration of approximately 6.84 years, and an average maturity of approximately 9.88 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.5 million and $91.8 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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $38.8 $0.1 More than 12 months 4.3 — Total $43.1 $0.1 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $89.7 $2.4 More than 12 months 79.8 3.4 Total $169.5 $5.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $11.2 $22.8 1 year - 5 years 187.7 188.0 5 years - 10 years 92.7 73.4 10 years - 15 years 3.0 5.2 15 years - 20 years 5.9 10.2 20 years+ 94.8 64.6 Total $395.3 $364.2 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $108.6 million and $157.8 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $1.7 million and $6.5 thousand , respectively, and gross losses of $0.2 million and $0.3 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $238.4 million and $357.2 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $3.6 million and $0.3 million , respectively, and gross losses of $0.6 million and $4.8 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates the available-for-sale debt securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred. The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three and nine months ended September 30, 2019 and 2018
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, Indian Point 1, Indian Point 2, Indian Point 3, 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 16 to the financial statements herein and Note 14 to the financial statements in the Form 10-K, in January 2019, Entergy completed the transfer of the Vermont Yankee plant to NorthStar. As part of the transaction, Entergy transferred the Vermont Yankee decommissioning trust fund to NorthStar. As of December 31, 2018, the fair value of the decommissioning trust fund was $532 million . As discussed in Note 16 to the financial statements herein, in August 2019, Entergy completed the transfer of the Pilgrim plant to Holtec. As part of the transaction, Entergy transferred the Pilgrim decommissioning trust fund to Holtec. The disposition-date fair value of the decommissioning trust fund was approximately $1,030 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 Indian Point 1, Indian Point 2, Indian Point 3, and Palisades 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 are 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 are recognized in earnings. 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 nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $17 million and $491 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities (a) $2,462 $114 $2 2018 Debt Securities (a) $2,495 $19 $35 (a) Debt securities presented herein do not include the $506 million and $389 million of debt securities held in the wholly-owned registered investment company as of September 30, 2019 and December 31, 2018 , respectively, which are not accounted for as available-for-sale. The unrealized gains/(losses) above are reported before deferred taxes of $16 million as of September 30, 2019 and ($1) million as of December 31, 2018 for debt securities. The amortized cost of available-for-sale debt securities was $2,362 million as of September 30, 2019 and $2,511 million as of December 31, 2018 . As of September 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 3.15% , an average duration of approximately 5.63 years, and an average maturity of approximately 9.02 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $236 $2 More than 12 months 67 — Total $303 $2 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $652 $9 More than 12 months 782 26 Total $1,434 $35 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $165 $199 1 year - 5 years 870 1,066 5 years - 10 years 636 544 10 years - 15 years 89 77 15 years - 20 years 98 78 20 years+ 604 531 Total $2,462 $2,495 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $407 million and $2,377 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $11 million and $4 million , respectively, and gross losses of $0.4 million and $15 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $1,133 million and $4,178 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $20 million and $6 million , respectively, and gross losses of $3 million and $37 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of September 30, 2019 are $534 million for Indian Point 1, $676 million for Indian Point 2, $893 million for Indian Point 3, and $492 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2018 are $471 million for Indian Point 1, $598 million for Indian Point 2, $781 million for Indian Point 3, $444 million for Palisades, $1,028 million for Pilgrim, and $532 million for Vermont Yankee. 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $407.7 $11.8 $0.9 2018 Debt Securities $381.3 $0.6 $8.2 The amortized cost of available-for-sale debt securities was $396.8 million as of September 30, 2019 and $389 million as of December 31, 2018 . As of September 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 2.78% , an average duration of approximately 5.57 years, and an average maturity of approximately 8.13 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.6 million and $96.5 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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $51.5 $0.8 More than 12 months 21.0 0.1 Total $72.5 $0.9 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $65.8 $0.5 More than 12 months 231.1 7.7 Total $296.9 $8.2 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $50.3 $32.5 1 year - 5 years 120.4 170.3 5 years - 10 years 144.5 114.0 10 years - 15 years 24.3 10.3 15 years - 20 years 14.2 8.1 20 years+ 54.0 46.1 Total $407.7 $381.3 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $45.5 million and $137.9 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $2 million and $0.01 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2018, gross losses of $0.6 million related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2019 , there were no gross losses. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $78.7 million and $259.3 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $2.1 million and $0.1 million , respectively, and gross losses of $0.1 million and $3 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $593.4 $32.6 $0.3 2018 Debt Securities $532.9 $4.1 $6.0 The amortized cost of available-for-sale debt securities was $561 million as of September 30, 2019 and $534.8 million as of December 31, 2018 . As of September 30, 2019 , the available-for-sale debt securities have an average coupon rate of approximately 3.85% , an average duration of approximately 6.53 years, and an average maturity of approximately 13.11 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $6 million and $137.2 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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $49.3 $0.3 More than 12 months 12.9 — Total $62.2 $0.3 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $170.1 $2.1 More than 12 months 145.8 3.9 Total $315.9 $6.0 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $56.6 $31.1 1 year - 5 years 138.2 130.5 5 years - 10 years 118.4 111.0 10 years - 15 years 34.7 29.0 15 years - 20 years 45.0 37.1 20 years+ 200.5 194.2 Total $593.4 $532.9 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $59.7 million and $773.9 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $2.5 million and $1.9 million , respectively, and gross losses of $29 thousand and $3.6 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $155.4 million and $943.3 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $4.2 million and $2.5 million , respectively, and gross losses of $0.2 million and $4.8 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $395.3 $19.7 $0.1 2018 Debt Securities $364.2 $2.9 $5.8 The amortized cost of available-for-sale debt securities was $375.6 million as of September 30, 2019 and $367.1 million as of December 31, 2018 . As of September 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 3.09% , an average duration of approximately 6.84 years, and an average maturity of approximately 9.88 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.5 million and $91.8 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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $38.8 $0.1 More than 12 months 4.3 — Total $43.1 $0.1 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $89.7 $2.4 More than 12 months 79.8 3.4 Total $169.5 $5.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $11.2 $22.8 1 year - 5 years 187.7 188.0 5 years - 10 years 92.7 73.4 10 years - 15 years 3.0 5.2 15 years - 20 years 5.9 10.2 20 years+ 94.8 64.6 Total $395.3 $364.2 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $108.6 million and $157.8 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $1.7 million and $6.5 thousand , respectively, and gross losses of $0.2 million and $0.3 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $238.4 million and $357.2 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $3.6 million and $0.3 million , respectively, and gross losses of $0.6 million and $4.8 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates the available-for-sale debt securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred. The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three and nine months ended September 30, 2019 and 2018
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, Indian Point 1, Indian Point 2, Indian Point 3, 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 16 to the financial statements herein and Note 14 to the financial statements in the Form 10-K, in January 2019, Entergy completed the transfer of the Vermont Yankee plant to NorthStar. As part of the transaction, Entergy transferred the Vermont Yankee decommissioning trust fund to NorthStar. As of December 31, 2018, the fair value of the decommissioning trust fund was $532 million . As discussed in Note 16 to the financial statements herein, in August 2019, Entergy completed the transfer of the Pilgrim plant to Holtec. As part of the transaction, Entergy transferred the Pilgrim decommissioning trust fund to Holtec. The disposition-date fair value of the decommissioning trust fund was approximately $1,030 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 Indian Point 1, Indian Point 2, Indian Point 3, and Palisades 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 are 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 are recognized in earnings. 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 nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $17 million and $491 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities (a) $2,462 $114 $2 2018 Debt Securities (a) $2,495 $19 $35 (a) Debt securities presented herein do not include the $506 million and $389 million of debt securities held in the wholly-owned registered investment company as of September 30, 2019 and December 31, 2018 , respectively, which are not accounted for as available-for-sale. The unrealized gains/(losses) above are reported before deferred taxes of $16 million as of September 30, 2019 and ($1) million as of December 31, 2018 for debt securities. The amortized cost of available-for-sale debt securities was $2,362 million as of September 30, 2019 and $2,511 million as of December 31, 2018 . As of September 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 3.15% , an average duration of approximately 5.63 years, and an average maturity of approximately 9.02 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $236 $2 More than 12 months 67 — Total $303 $2 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $652 $9 More than 12 months 782 26 Total $1,434 $35 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $165 $199 1 year - 5 years 870 1,066 5 years - 10 years 636 544 10 years - 15 years 89 77 15 years - 20 years 98 78 20 years+ 604 531 Total $2,462 $2,495 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $407 million and $2,377 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $11 million and $4 million , respectively, and gross losses of $0.4 million and $15 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $1,133 million and $4,178 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $20 million and $6 million , respectively, and gross losses of $3 million and $37 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of September 30, 2019 are $534 million for Indian Point 1, $676 million for Indian Point 2, $893 million for Indian Point 3, and $492 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2018 are $471 million for Indian Point 1, $598 million for Indian Point 2, $781 million for Indian Point 3, $444 million for Palisades, $1,028 million for Pilgrim, and $532 million for Vermont Yankee. 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $407.7 $11.8 $0.9 2018 Debt Securities $381.3 $0.6 $8.2 The amortized cost of available-for-sale debt securities was $396.8 million as of September 30, 2019 and $389 million as of December 31, 2018 . As of September 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 2.78% , an average duration of approximately 5.57 years, and an average maturity of approximately 8.13 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.6 million and $96.5 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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $51.5 $0.8 More than 12 months 21.0 0.1 Total $72.5 $0.9 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $65.8 $0.5 More than 12 months 231.1 7.7 Total $296.9 $8.2 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $50.3 $32.5 1 year - 5 years 120.4 170.3 5 years - 10 years 144.5 114.0 10 years - 15 years 24.3 10.3 15 years - 20 years 14.2 8.1 20 years+ 54.0 46.1 Total $407.7 $381.3 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $45.5 million and $137.9 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $2 million and $0.01 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2018, gross losses of $0.6 million related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2019 , there were no gross losses. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $78.7 million and $259.3 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $2.1 million and $0.1 million , respectively, and gross losses of $0.1 million and $3 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $593.4 $32.6 $0.3 2018 Debt Securities $532.9 $4.1 $6.0 The amortized cost of available-for-sale debt securities was $561 million as of September 30, 2019 and $534.8 million as of December 31, 2018 . As of September 30, 2019 , the available-for-sale debt securities have an average coupon rate of approximately 3.85% , an average duration of approximately 6.53 years, and an average maturity of approximately 13.11 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $6 million and $137.2 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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $49.3 $0.3 More than 12 months 12.9 — Total $62.2 $0.3 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $170.1 $2.1 More than 12 months 145.8 3.9 Total $315.9 $6.0 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $56.6 $31.1 1 year - 5 years 138.2 130.5 5 years - 10 years 118.4 111.0 10 years - 15 years 34.7 29.0 15 years - 20 years 45.0 37.1 20 years+ 200.5 194.2 Total $593.4 $532.9 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $59.7 million and $773.9 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $2.5 million and $1.9 million , respectively, and gross losses of $29 thousand and $3.6 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $155.4 million and $943.3 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $4.2 million and $2.5 million , respectively, and gross losses of $0.2 million and $4.8 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 September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $395.3 $19.7 $0.1 2018 Debt Securities $364.2 $2.9 $5.8 The amortized cost of available-for-sale debt securities was $375.6 million as of September 30, 2019 and $367.1 million as of December 31, 2018 . As of September 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 3.09% , an average duration of approximately 6.84 years, and an average maturity of approximately 9.88 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.5 million and $91.8 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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $38.8 $0.1 More than 12 months 4.3 — Total $43.1 $0.1 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $89.7 $2.4 More than 12 months 79.8 3.4 Total $169.5 $5.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $11.2 $22.8 1 year - 5 years 187.7 188.0 5 years - 10 years 92.7 73.4 10 years - 15 years 3.0 5.2 15 years - 20 years 5.9 10.2 20 years+ 94.8 64.6 Total $395.3 $364.2 During the three months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $108.6 million and $157.8 million , respectively. During the three months ended September 30, 2019 and 2018 , gross gains of $1.7 million and $6.5 thousand , respectively, and gross losses of $0.2 million and $0.3 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $238.4 million and $357.2 million , respectively. During the nine months ended September 30, 2019 and 2018 , gross gains of $3.6 million and $0.3 million , respectively, and gross losses of $0.6 million and $4.8 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates the available-for-sale debt securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred. The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three and nine months ended September 30, 2019 and 2018

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2019
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, 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 commissions. 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 has a significant effect on 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 Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (In Millions) Entergy $96 $283 $219 $562 Entergy Arkansas $41 $153 $99 $260 Entergy Louisiana $17 $55 $31 $86 Entergy Mississippi $— $32 $— $161 Entergy New Orleans $7 $9 $9 $9 Entergy Texas $31 $— $73 $— System Entergy $— $34 $7 $46 Other Tax Matters In April 2019 the state of Arkansas enacted corporate income tax law changes that phase in an Arkansas tax rate reduction from the current rate of 6.5% to 6.2% in 2021 and 5.9% in 2022. The rate reduction will eventually reduce Entergy Arkansas’s combined federal and state applicable tax rate by less than 0.5% once fully adopted. As a result of the rate reduction, Entergy Arkansas recorded a regulatory liability for income taxes of approximately $25 million which includes a tax gross-up related to the treatment of income taxes in the ratemaking formula. The Arkansas tax law enactment also phases in an increase to the net operating loss carryover period from five to ten years. In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group. Additionally, in September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock with a liquidation value of $25 per share resulting in the disaffiliation and de-consolidation of Entergy Texas from the consolidated federal income tax return of Entergy Corporation. These changes will not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. See Note 3 to the financial statements herein for discussion of the preferred stock issuance. Vermont Yankee The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. See Note 16 to the financial statements herein for discussion of the Vermont Yankee transaction.
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, 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 commissions. 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 has a significant effect on 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 Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (In Millions) Entergy $96 $283 $219 $562 Entergy Arkansas $41 $153 $99 $260 Entergy Louisiana $17 $55 $31 $86 Entergy Mississippi $— $32 $— $161 Entergy New Orleans $7 $9 $9 $9 Entergy Texas $31 $— $73 $— System Entergy $— $34 $7 $46 Other Tax Matters In April 2019 the state of Arkansas enacted corporate income tax law changes that phase in an Arkansas tax rate reduction from the current rate of 6.5% to 6.2% in 2021 and 5.9% in 2022. The rate reduction will eventually reduce Entergy Arkansas’s combined federal and state applicable tax rate by less than 0.5% once fully adopted. As a result of the rate reduction, Entergy Arkansas recorded a regulatory liability for income taxes of approximately $25 million which includes a tax gross-up related to the treatment of income taxes in the ratemaking formula. The Arkansas tax law enactment also phases in an increase to the net operating loss carryover period from five to ten years. In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group. Additionally, in September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock with a liquidation value of $25 per share resulting in the disaffiliation and de-consolidation of Entergy Texas from the consolidated federal income tax return of Entergy Corporation. These changes will not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. See Note 3 to the financial statements herein for discussion of the preferred stock issuance. Vermont Yankee The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. See Note 16 to the financial statements herein for discussion of the Vermont Yankee transaction.
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, 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 commissions. 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 has a significant effect on 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 Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (In Millions) Entergy $96 $283 $219 $562 Entergy Arkansas $41 $153 $99 $260 Entergy Louisiana $17 $55 $31 $86 Entergy Mississippi $— $32 $— $161 Entergy New Orleans $7 $9 $9 $9 Entergy Texas $31 $— $73 $— System Entergy $— $34 $7 $46 Other Tax Matters In April 2019 the state of Arkansas enacted corporate income tax law changes that phase in an Arkansas tax rate reduction from the current rate of 6.5% to 6.2% in 2021 and 5.9% in 2022. The rate reduction will eventually reduce Entergy Arkansas’s combined federal and state applicable tax rate by less than 0.5% once fully adopted. As a result of the rate reduction, Entergy Arkansas recorded a regulatory liability for income taxes of approximately $25 million which includes a tax gross-up related to the treatment of income taxes in the ratemaking formula. The Arkansas tax law enactment also phases in an increase to the net operating loss carryover period from five to ten years. In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group. Additionally, in September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock with a liquidation value of $25 per share resulting in the disaffiliation and de-consolidation of Entergy Texas from the consolidated federal income tax return of Entergy Corporation. These changes will not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. See Note 3 to the financial statements herein for discussion of the preferred stock issuance. Vermont Yankee The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. See Note 16 to the financial statements herein for discussion of the Vermont Yankee transaction.
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, 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 commissions. 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 has a significant effect on 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 Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (In Millions) Entergy $96 $283 $219 $562 Entergy Arkansas $41 $153 $99 $260 Entergy Louisiana $17 $55 $31 $86 Entergy Mississippi $— $32 $— $161 Entergy New Orleans $7 $9 $9 $9 Entergy Texas $31 $— $73 $— System Entergy $— $34 $7 $46 Other Tax Matters In April 2019 the state of Arkansas enacted corporate income tax law changes that phase in an Arkansas tax rate reduction from the current rate of 6.5% to 6.2% in 2021 and 5.9% in 2022. The rate reduction will eventually reduce Entergy Arkansas’s combined federal and state applicable tax rate by less than 0.5% once fully adopted. As a result of the rate reduction, Entergy Arkansas recorded a regulatory liability for income taxes of approximately $25 million which includes a tax gross-up related to the treatment of income taxes in the ratemaking formula. The Arkansas tax law enactment also phases in an increase to the net operating loss carryover period from five to ten years. In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group. Additionally, in September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock with a liquidation value of $25 per share resulting in the disaffiliation and de-consolidation of Entergy Texas from the consolidated federal income tax return of Entergy Corporation. These changes will not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. See Note 3 to the financial statements herein for discussion of the preferred stock issuance. Vermont Yankee The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. See Note 16 to the financial statements herein for discussion of the Vermont Yankee transaction.
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, 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 commissions. 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 has a significant effect on 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 Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (In Millions) Entergy $96 $283 $219 $562 Entergy Arkansas $41 $153 $99 $260 Entergy Louisiana $17 $55 $31 $86 Entergy Mississippi $— $32 $— $161 Entergy New Orleans $7 $9 $9 $9 Entergy Texas $31 $— $73 $— System Entergy $— $34 $7 $46 Other Tax Matters In April 2019 the state of Arkansas enacted corporate income tax law changes that phase in an Arkansas tax rate reduction from the current rate of 6.5% to 6.2% in 2021 and 5.9% in 2022. The rate reduction will eventually reduce Entergy Arkansas’s combined federal and state applicable tax rate by less than 0.5% once fully adopted. As a result of the rate reduction, Entergy Arkansas recorded a regulatory liability for income taxes of approximately $25 million which includes a tax gross-up related to the treatment of income taxes in the ratemaking formula. The Arkansas tax law enactment also phases in an increase to the net operating loss carryover period from five to ten years. In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group. Additionally, in September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock with a liquidation value of $25 per share resulting in the disaffiliation and de-consolidation of Entergy Texas from the consolidated federal income tax return of Entergy Corporation. These changes will not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. See Note 3 to the financial statements herein for discussion of the preferred stock issuance. Vermont Yankee The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. See Note 16 to the financial statements herein for discussion of the Vermont Yankee transaction.
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, 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 commissions. 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 has a significant effect on 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 Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (In Millions) Entergy $96 $283 $219 $562 Entergy Arkansas $41 $153 $99 $260 Entergy Louisiana $17 $55 $31 $86 Entergy Mississippi $— $32 $— $161 Entergy New Orleans $7 $9 $9 $9 Entergy Texas $31 $— $73 $— System Entergy $— $34 $7 $46 Other Tax Matters In April 2019 the state of Arkansas enacted corporate income tax law changes that phase in an Arkansas tax rate reduction from the current rate of 6.5% to 6.2% in 2021 and 5.9% in 2022. The rate reduction will eventually reduce Entergy Arkansas’s combined federal and state applicable tax rate by less than 0.5% once fully adopted. As a result of the rate reduction, Entergy Arkansas recorded a regulatory liability for income taxes of approximately $25 million which includes a tax gross-up related to the treatment of income taxes in the ratemaking formula. The Arkansas tax law enactment also phases in an increase to the net operating loss carryover period from five to ten years. In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group. Additionally, in September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock with a liquidation value of $25 per share resulting in the disaffiliation and de-consolidation of Entergy Texas from the consolidated federal income tax return of Entergy Corporation. These changes will not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. See Note 3 to the financial statements herein for discussion of the preferred stock issuance. Vermont Yankee The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. See Note 16 to the financial statements herein for discussion of the Vermont Yankee transaction.
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, 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 commissions. 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 has a significant effect on 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 Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (In Millions) Entergy $96 $283 $219 $562 Entergy Arkansas $41 $153 $99 $260 Entergy Louisiana $17 $55 $31 $86 Entergy Mississippi $— $32 $— $161 Entergy New Orleans $7 $9 $9 $9 Entergy Texas $31 $— $73 $— System Entergy $— $34 $7 $46 Other Tax Matters In April 2019 the state of Arkansas enacted corporate income tax law changes that phase in an Arkansas tax rate reduction from the current rate of 6.5% to 6.2% in 2021 and 5.9% in 2022. The rate reduction will eventually reduce Entergy Arkansas’s combined federal and state applicable tax rate by less than 0.5% once fully adopted. As a result of the rate reduction, Entergy Arkansas recorded a regulatory liability for income taxes of approximately $25 million which includes a tax gross-up related to the treatment of income taxes in the ratemaking formula. The Arkansas tax law enactment also phases in an increase to the net operating loss carryover period from five to ten years. In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group. Additionally, in September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock with a liquidation value of $25 per share resulting in the disaffiliation and de-consolidation of Entergy Texas from the consolidated federal income tax return of Entergy Corporation. These changes will not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. See Note 3 to the financial statements herein for discussion of the preferred stock issuance. Vermont Yankee The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. See Note 16 to the financial statements herein for discussion of the Vermont Yankee transaction.

Property, Plant, And Equipment

Property, Plant, And Equipment	9 Months Ended
	Sep. 30, 2019
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 September 30, 2019 are $306 million for Entergy, $41.7 million for Entergy Arkansas, $74 million for Entergy Louisiana, $14.7 million for Entergy Mississippi, $13.9 million for Entergy New Orleans, $81.6 million for Entergy Texas, and $24.6 million for System Energy. Construction expenditures included in accounts payable at December 31, 2018 are $311 million for Entergy, $35.7 million for Entergy Arkansas, $104.6 million for Entergy Louisiana, $13.6 million for Entergy Mississippi, $5.8 million for Entergy New Orleans, $55.6 million for Entergy Texas, and $26.3 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 September 30, 2019 are $306 million for Entergy, $41.7 million for Entergy Arkansas, $74 million for Entergy Louisiana, $14.7 million for Entergy Mississippi, $13.9 million for Entergy New Orleans, $81.6 million for Entergy Texas, and $24.6 million for System Energy. Construction expenditures included in accounts payable at December 31, 2018 are $311 million for Entergy, $35.7 million for Entergy Arkansas, $104.6 million for Entergy Louisiana, $13.6 million for Entergy Mississippi, $5.8 million for Entergy New Orleans, $55.6 million for Entergy Texas, and $26.3 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 September 30, 2019 are $306 million for Entergy, $41.7 million for Entergy Arkansas, $74 million for Entergy Louisiana, $14.7 million for Entergy Mississippi, $13.9 million for Entergy New Orleans, $81.6 million for Entergy Texas, and $24.6 million for System Energy. Construction expenditures included in accounts payable at December 31, 2018 are $311 million for Entergy, $35.7 million for Entergy Arkansas, $104.6 million for Entergy Louisiana, $13.6 million for Entergy Mississippi, $5.8 million for Entergy New Orleans, $55.6 million for Entergy Texas, and $26.3 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 September 30, 2019 are $306 million for Entergy, $41.7 million for Entergy Arkansas, $74 million for Entergy Louisiana, $14.7 million for Entergy Mississippi, $13.9 million for Entergy New Orleans, $81.6 million for Entergy Texas, and $24.6 million for System Energy. Construction expenditures included in accounts payable at December 31, 2018 are $311 million for Entergy, $35.7 million for Entergy Arkansas, $104.6 million for Entergy Louisiana, $13.6 million for Entergy Mississippi, $5.8 million for Entergy New Orleans, $55.6 million for Entergy Texas, and $26.3 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 September 30, 2019 are $306 million for Entergy, $41.7 million for Entergy Arkansas, $74 million for Entergy Louisiana, $14.7 million for Entergy Mississippi, $13.9 million for Entergy New Orleans, $81.6 million for Entergy Texas, and $24.6 million for System Energy. Construction expenditures included in accounts payable at December 31, 2018 are $311 million for Entergy, $35.7 million for Entergy Arkansas, $104.6 million for Entergy Louisiana, $13.6 million for Entergy Mississippi, $5.8 million for Entergy New Orleans, $55.6 million for Entergy Texas, and $26.3 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 September 30, 2019 are $306 million for Entergy, $41.7 million for Entergy Arkansas, $74 million for Entergy Louisiana, $14.7 million for Entergy Mississippi, $13.9 million for Entergy New Orleans, $81.6 million for Entergy Texas, and $24.6 million for System Energy. Construction expenditures included in accounts payable at December 31, 2018 are $311 million for Entergy, $35.7 million for Entergy Arkansas, $104.6 million for Entergy Louisiana, $13.6 million for Entergy Mississippi, $5.8 million for Entergy New Orleans, $55.6 million for Entergy Texas, and $26.3 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 September 30, 2019 are $306 million for Entergy, $41.7 million for Entergy Arkansas, $74 million for Entergy Louisiana, $14.7 million for Entergy Mississippi, $13.9 million for Entergy New Orleans, $81.6 million for Entergy Texas, and $24.6 million for System Energy. Construction expenditures included in accounts payable at December 31, 2018 are $311 million for Entergy, $35.7 million for Entergy Arkansas, $104.6 million for Entergy Louisiana, $13.6 million for Entergy Mississippi, $5.8 million for Entergy New Orleans, $55.6 million for Entergy Texas, and $26.3 million for System Energy.

Variable Interest Entities

Variable Interest Entities	9 Months Ended
	Sep. 30, 2019
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 and 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 10 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2019 and in the three months ended September 30, 2018 . System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2019 and in the nine months ended September 30, 2018
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 and 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 10 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2019 and in the three months ended September 30, 2018 . System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2019 and in the nine months ended September 30, 2018
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 and 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 10 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2019 and in the three months ended September 30, 2018 . System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2019 and in the nine months ended September 30, 2018
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 and 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 10 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2019 and in the three months ended September 30, 2018 . System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2019 and in the nine months ended September 30, 2018
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 and 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 10 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2019 and in the three months ended September 30, 2018 . System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2019 and in the nine months ended September 30, 2018
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 and 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 10 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2019 and in the three months ended September 30, 2018 . System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2019 and in the nine months ended September 30, 2018
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 and 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 10 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2019 and in the three months ended September 30, 2018 . System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2019 and in the nine months ended September 30, 2018

Revenue Recognition

Revenue Recognition	9 Months Ended
	Sep. 30, 2019
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) 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 September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,154,455 $1,138,744 Commercial 722,334 693,760 Industrial 686,122 682,823 Governmental 61,697 60,647 Total billed retail 2,624,608 2,575,974 Sales for resale (a) 63,082 76,247 Other electric revenues (b) 115,352 42,847 Non-customer revenues (c) 9,892 2,819 Total electric revenues 2,812,934 2,697,887 Natural gas 27,269 26,352 Entergy Wholesale Commodities: Competitive businesses sales (a) 282,420 407,763 Non-customer revenues (c) 17,952 (27,683 ) Total competitive businesses 300,372 380,080 Total operating revenues $3,140,575 $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $2,727,367 $2,799,539 Commercial 1,871,416 1,871,380 Industrial 1,928,857 1,904,828 Governmental 172,280 173,949 Total billed retail 6,699,920 6,749,696 Sales for resale (a) 222,834 214,984 Other electric revenues (b) 326,771 289,668 Non-customer revenues (c) 30,158 22,026 Total electric revenues 7,279,683 7,276,374 Natural gas 112,916 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 923,288 1,148,460 Non-customer revenues (c) 100,480 (40,854 ) Total competitive businesses 1,023,768 1,107,606 Total operating revenues $8,416,367 $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $253,627 $426,012 $177,785 $81,468 $215,563 Commercial 162,564 277,071 131,596 56,430 94,673 Industrial 156,024 376,595 44,054 8,613 100,836 Governmental 5,907 18,731 12,551 19,030 5,478 Total billed retail 578,122 1,098,409 365,986 165,541 416,550 Sales for resale (a) 58,953 81,664 9,569 6,876 16,704 Other electric revenues (b) 47,085 37,521 20,499 2,537 9,177 Non-customer revenues (c) 3,366 4,280 2,678 1,784 446 Total electric revenues 687,526 1,221,874 398,732 176,738 442,877 Natural gas — 9,803 — 17,466 — Total operating revenues $687,526 $1,231,677 $398,732 $194,204 $442,877 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $621,208 $980,443 $423,395 $192,165 $510,156 Commercial 412,697 715,983 331,785 156,152 254,799 Industrial 396,515 1,108,193 120,490 24,353 279,306 Governmental 15,776 53,547 33,108 53,916 15,933 Total billed retail 1,446,196 2,858,166 908,778 426,586 1,060,194 Sales for resale (a) 213,038 248,827 19,377 25,680 48,251 Other electric revenues (b) 107,599 130,269 47,887 8,093 37,329 Non-customer revenues (c) 9,434 15,564 7,671 4,414 1,157 Total electric revenues 1,776,267 3,252,826 983,713 464,773 1,146,931 Natural gas — 44,498 — 68,418 — Total operating revenues $1,776,267 $3,297,324 $983,713 $533,191 $1,146,931 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (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) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy Arkansas [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) 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 September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,154,455 $1,138,744 Commercial 722,334 693,760 Industrial 686,122 682,823 Governmental 61,697 60,647 Total billed retail 2,624,608 2,575,974 Sales for resale (a) 63,082 76,247 Other electric revenues (b) 115,352 42,847 Non-customer revenues (c) 9,892 2,819 Total electric revenues 2,812,934 2,697,887 Natural gas 27,269 26,352 Entergy Wholesale Commodities: Competitive businesses sales (a) 282,420 407,763 Non-customer revenues (c) 17,952 (27,683 ) Total competitive businesses 300,372 380,080 Total operating revenues $3,140,575 $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $2,727,367 $2,799,539 Commercial 1,871,416 1,871,380 Industrial 1,928,857 1,904,828 Governmental 172,280 173,949 Total billed retail 6,699,920 6,749,696 Sales for resale (a) 222,834 214,984 Other electric revenues (b) 326,771 289,668 Non-customer revenues (c) 30,158 22,026 Total electric revenues 7,279,683 7,276,374 Natural gas 112,916 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 923,288 1,148,460 Non-customer revenues (c) 100,480 (40,854 ) Total competitive businesses 1,023,768 1,107,606 Total operating revenues $8,416,367 $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $253,627 $426,012 $177,785 $81,468 $215,563 Commercial 162,564 277,071 131,596 56,430 94,673 Industrial 156,024 376,595 44,054 8,613 100,836 Governmental 5,907 18,731 12,551 19,030 5,478 Total billed retail 578,122 1,098,409 365,986 165,541 416,550 Sales for resale (a) 58,953 81,664 9,569 6,876 16,704 Other electric revenues (b) 47,085 37,521 20,499 2,537 9,177 Non-customer revenues (c) 3,366 4,280 2,678 1,784 446 Total electric revenues 687,526 1,221,874 398,732 176,738 442,877 Natural gas — 9,803 — 17,466 — Total operating revenues $687,526 $1,231,677 $398,732 $194,204 $442,877 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $621,208 $980,443 $423,395 $192,165 $510,156 Commercial 412,697 715,983 331,785 156,152 254,799 Industrial 396,515 1,108,193 120,490 24,353 279,306 Governmental 15,776 53,547 33,108 53,916 15,933 Total billed retail 1,446,196 2,858,166 908,778 426,586 1,060,194 Sales for resale (a) 213,038 248,827 19,377 25,680 48,251 Other electric revenues (b) 107,599 130,269 47,887 8,093 37,329 Non-customer revenues (c) 9,434 15,564 7,671 4,414 1,157 Total electric revenues 1,776,267 3,252,826 983,713 464,773 1,146,931 Natural gas — 44,498 — 68,418 — Total operating revenues $1,776,267 $3,297,324 $983,713 $533,191 $1,146,931 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (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) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy Louisiana [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) 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 September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,154,455 $1,138,744 Commercial 722,334 693,760 Industrial 686,122 682,823 Governmental 61,697 60,647 Total billed retail 2,624,608 2,575,974 Sales for resale (a) 63,082 76,247 Other electric revenues (b) 115,352 42,847 Non-customer revenues (c) 9,892 2,819 Total electric revenues 2,812,934 2,697,887 Natural gas 27,269 26,352 Entergy Wholesale Commodities: Competitive businesses sales (a) 282,420 407,763 Non-customer revenues (c) 17,952 (27,683 ) Total competitive businesses 300,372 380,080 Total operating revenues $3,140,575 $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $2,727,367 $2,799,539 Commercial 1,871,416 1,871,380 Industrial 1,928,857 1,904,828 Governmental 172,280 173,949 Total billed retail 6,699,920 6,749,696 Sales for resale (a) 222,834 214,984 Other electric revenues (b) 326,771 289,668 Non-customer revenues (c) 30,158 22,026 Total electric revenues 7,279,683 7,276,374 Natural gas 112,916 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 923,288 1,148,460 Non-customer revenues (c) 100,480 (40,854 ) Total competitive businesses 1,023,768 1,107,606 Total operating revenues $8,416,367 $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $253,627 $426,012 $177,785 $81,468 $215,563 Commercial 162,564 277,071 131,596 56,430 94,673 Industrial 156,024 376,595 44,054 8,613 100,836 Governmental 5,907 18,731 12,551 19,030 5,478 Total billed retail 578,122 1,098,409 365,986 165,541 416,550 Sales for resale (a) 58,953 81,664 9,569 6,876 16,704 Other electric revenues (b) 47,085 37,521 20,499 2,537 9,177 Non-customer revenues (c) 3,366 4,280 2,678 1,784 446 Total electric revenues 687,526 1,221,874 398,732 176,738 442,877 Natural gas — 9,803 — 17,466 — Total operating revenues $687,526 $1,231,677 $398,732 $194,204 $442,877 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $621,208 $980,443 $423,395 $192,165 $510,156 Commercial 412,697 715,983 331,785 156,152 254,799 Industrial 396,515 1,108,193 120,490 24,353 279,306 Governmental 15,776 53,547 33,108 53,916 15,933 Total billed retail 1,446,196 2,858,166 908,778 426,586 1,060,194 Sales for resale (a) 213,038 248,827 19,377 25,680 48,251 Other electric revenues (b) 107,599 130,269 47,887 8,093 37,329 Non-customer revenues (c) 9,434 15,564 7,671 4,414 1,157 Total electric revenues 1,776,267 3,252,826 983,713 464,773 1,146,931 Natural gas — 44,498 — 68,418 — Total operating revenues $1,776,267 $3,297,324 $983,713 $533,191 $1,146,931 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (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) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy Mississippi [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) 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 September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,154,455 $1,138,744 Commercial 722,334 693,760 Industrial 686,122 682,823 Governmental 61,697 60,647 Total billed retail 2,624,608 2,575,974 Sales for resale (a) 63,082 76,247 Other electric revenues (b) 115,352 42,847 Non-customer revenues (c) 9,892 2,819 Total electric revenues 2,812,934 2,697,887 Natural gas 27,269 26,352 Entergy Wholesale Commodities: Competitive businesses sales (a) 282,420 407,763 Non-customer revenues (c) 17,952 (27,683 ) Total competitive businesses 300,372 380,080 Total operating revenues $3,140,575 $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $2,727,367 $2,799,539 Commercial 1,871,416 1,871,380 Industrial 1,928,857 1,904,828 Governmental 172,280 173,949 Total billed retail 6,699,920 6,749,696 Sales for resale (a) 222,834 214,984 Other electric revenues (b) 326,771 289,668 Non-customer revenues (c) 30,158 22,026 Total electric revenues 7,279,683 7,276,374 Natural gas 112,916 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 923,288 1,148,460 Non-customer revenues (c) 100,480 (40,854 ) Total competitive businesses 1,023,768 1,107,606 Total operating revenues $8,416,367 $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $253,627 $426,012 $177,785 $81,468 $215,563 Commercial 162,564 277,071 131,596 56,430 94,673 Industrial 156,024 376,595 44,054 8,613 100,836 Governmental 5,907 18,731 12,551 19,030 5,478 Total billed retail 578,122 1,098,409 365,986 165,541 416,550 Sales for resale (a) 58,953 81,664 9,569 6,876 16,704 Other electric revenues (b) 47,085 37,521 20,499 2,537 9,177 Non-customer revenues (c) 3,366 4,280 2,678 1,784 446 Total electric revenues 687,526 1,221,874 398,732 176,738 442,877 Natural gas — 9,803 — 17,466 — Total operating revenues $687,526 $1,231,677 $398,732 $194,204 $442,877 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $621,208 $980,443 $423,395 $192,165 $510,156 Commercial 412,697 715,983 331,785 156,152 254,799 Industrial 396,515 1,108,193 120,490 24,353 279,306 Governmental 15,776 53,547 33,108 53,916 15,933 Total billed retail 1,446,196 2,858,166 908,778 426,586 1,060,194 Sales for resale (a) 213,038 248,827 19,377 25,680 48,251 Other electric revenues (b) 107,599 130,269 47,887 8,093 37,329 Non-customer revenues (c) 9,434 15,564 7,671 4,414 1,157 Total electric revenues 1,776,267 3,252,826 983,713 464,773 1,146,931 Natural gas — 44,498 — 68,418 — Total operating revenues $1,776,267 $3,297,324 $983,713 $533,191 $1,146,931 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (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) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy New Orleans [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) 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 September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,154,455 $1,138,744 Commercial 722,334 693,760 Industrial 686,122 682,823 Governmental 61,697 60,647 Total billed retail 2,624,608 2,575,974 Sales for resale (a) 63,082 76,247 Other electric revenues (b) 115,352 42,847 Non-customer revenues (c) 9,892 2,819 Total electric revenues 2,812,934 2,697,887 Natural gas 27,269 26,352 Entergy Wholesale Commodities: Competitive businesses sales (a) 282,420 407,763 Non-customer revenues (c) 17,952 (27,683 ) Total competitive businesses 300,372 380,080 Total operating revenues $3,140,575 $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $2,727,367 $2,799,539 Commercial 1,871,416 1,871,380 Industrial 1,928,857 1,904,828 Governmental 172,280 173,949 Total billed retail 6,699,920 6,749,696 Sales for resale (a) 222,834 214,984 Other electric revenues (b) 326,771 289,668 Non-customer revenues (c) 30,158 22,026 Total electric revenues 7,279,683 7,276,374 Natural gas 112,916 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 923,288 1,148,460 Non-customer revenues (c) 100,480 (40,854 ) Total competitive businesses 1,023,768 1,107,606 Total operating revenues $8,416,367 $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $253,627 $426,012 $177,785 $81,468 $215,563 Commercial 162,564 277,071 131,596 56,430 94,673 Industrial 156,024 376,595 44,054 8,613 100,836 Governmental 5,907 18,731 12,551 19,030 5,478 Total billed retail 578,122 1,098,409 365,986 165,541 416,550 Sales for resale (a) 58,953 81,664 9,569 6,876 16,704 Other electric revenues (b) 47,085 37,521 20,499 2,537 9,177 Non-customer revenues (c) 3,366 4,280 2,678 1,784 446 Total electric revenues 687,526 1,221,874 398,732 176,738 442,877 Natural gas — 9,803 — 17,466 — Total operating revenues $687,526 $1,231,677 $398,732 $194,204 $442,877 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $621,208 $980,443 $423,395 $192,165 $510,156 Commercial 412,697 715,983 331,785 156,152 254,799 Industrial 396,515 1,108,193 120,490 24,353 279,306 Governmental 15,776 53,547 33,108 53,916 15,933 Total billed retail 1,446,196 2,858,166 908,778 426,586 1,060,194 Sales for resale (a) 213,038 248,827 19,377 25,680 48,251 Other electric revenues (b) 107,599 130,269 47,887 8,093 37,329 Non-customer revenues (c) 9,434 15,564 7,671 4,414 1,157 Total electric revenues 1,776,267 3,252,826 983,713 464,773 1,146,931 Natural gas — 44,498 — 68,418 — Total operating revenues $1,776,267 $3,297,324 $983,713 $533,191 $1,146,931 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (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) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy Texas [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) 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 September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,154,455 $1,138,744 Commercial 722,334 693,760 Industrial 686,122 682,823 Governmental 61,697 60,647 Total billed retail 2,624,608 2,575,974 Sales for resale (a) 63,082 76,247 Other electric revenues (b) 115,352 42,847 Non-customer revenues (c) 9,892 2,819 Total electric revenues 2,812,934 2,697,887 Natural gas 27,269 26,352 Entergy Wholesale Commodities: Competitive businesses sales (a) 282,420 407,763 Non-customer revenues (c) 17,952 (27,683 ) Total competitive businesses 300,372 380,080 Total operating revenues $3,140,575 $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $2,727,367 $2,799,539 Commercial 1,871,416 1,871,380 Industrial 1,928,857 1,904,828 Governmental 172,280 173,949 Total billed retail 6,699,920 6,749,696 Sales for resale (a) 222,834 214,984 Other electric revenues (b) 326,771 289,668 Non-customer revenues (c) 30,158 22,026 Total electric revenues 7,279,683 7,276,374 Natural gas 112,916 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 923,288 1,148,460 Non-customer revenues (c) 100,480 (40,854 ) Total competitive businesses 1,023,768 1,107,606 Total operating revenues $8,416,367 $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $253,627 $426,012 $177,785 $81,468 $215,563 Commercial 162,564 277,071 131,596 56,430 94,673 Industrial 156,024 376,595 44,054 8,613 100,836 Governmental 5,907 18,731 12,551 19,030 5,478 Total billed retail 578,122 1,098,409 365,986 165,541 416,550 Sales for resale (a) 58,953 81,664 9,569 6,876 16,704 Other electric revenues (b) 47,085 37,521 20,499 2,537 9,177 Non-customer revenues (c) 3,366 4,280 2,678 1,784 446 Total electric revenues 687,526 1,221,874 398,732 176,738 442,877 Natural gas — 9,803 — 17,466 — Total operating revenues $687,526 $1,231,677 $398,732 $194,204 $442,877 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $621,208 $980,443 $423,395 $192,165 $510,156 Commercial 412,697 715,983 331,785 156,152 254,799 Industrial 396,515 1,108,193 120,490 24,353 279,306 Governmental 15,776 53,547 33,108 53,916 15,933 Total billed retail 1,446,196 2,858,166 908,778 426,586 1,060,194 Sales for resale (a) 213,038 248,827 19,377 25,680 48,251 Other electric revenues (b) 107,599 130,269 47,887 8,093 37,329 Non-customer revenues (c) 9,434 15,564 7,671 4,414 1,157 Total electric revenues 1,776,267 3,252,826 983,713 464,773 1,146,931 Natural gas — 44,498 — 68,418 — Total operating revenues $1,776,267 $3,297,324 $983,713 $533,191 $1,146,931 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (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) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
System Energy [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) 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 September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,154,455 $1,138,744 Commercial 722,334 693,760 Industrial 686,122 682,823 Governmental 61,697 60,647 Total billed retail 2,624,608 2,575,974 Sales for resale (a) 63,082 76,247 Other electric revenues (b) 115,352 42,847 Non-customer revenues (c) 9,892 2,819 Total electric revenues 2,812,934 2,697,887 Natural gas 27,269 26,352 Entergy Wholesale Commodities: Competitive businesses sales (a) 282,420 407,763 Non-customer revenues (c) 17,952 (27,683 ) Total competitive businesses 300,372 380,080 Total operating revenues $3,140,575 $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $2,727,367 $2,799,539 Commercial 1,871,416 1,871,380 Industrial 1,928,857 1,904,828 Governmental 172,280 173,949 Total billed retail 6,699,920 6,749,696 Sales for resale (a) 222,834 214,984 Other electric revenues (b) 326,771 289,668 Non-customer revenues (c) 30,158 22,026 Total electric revenues 7,279,683 7,276,374 Natural gas 112,916 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 923,288 1,148,460 Non-customer revenues (c) 100,480 (40,854 ) Total competitive businesses 1,023,768 1,107,606 Total operating revenues $8,416,367 $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $253,627 $426,012 $177,785 $81,468 $215,563 Commercial 162,564 277,071 131,596 56,430 94,673 Industrial 156,024 376,595 44,054 8,613 100,836 Governmental 5,907 18,731 12,551 19,030 5,478 Total billed retail 578,122 1,098,409 365,986 165,541 416,550 Sales for resale (a) 58,953 81,664 9,569 6,876 16,704 Other electric revenues (b) 47,085 37,521 20,499 2,537 9,177 Non-customer revenues (c) 3,366 4,280 2,678 1,784 446 Total electric revenues 687,526 1,221,874 398,732 176,738 442,877 Natural gas — 9,803 — 17,466 — Total operating revenues $687,526 $1,231,677 $398,732 $194,204 $442,877 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $621,208 $980,443 $423,395 $192,165 $510,156 Commercial 412,697 715,983 331,785 156,152 254,799 Industrial 396,515 1,108,193 120,490 24,353 279,306 Governmental 15,776 53,547 33,108 53,916 15,933 Total billed retail 1,446,196 2,858,166 908,778 426,586 1,060,194 Sales for resale (a) 213,038 248,827 19,377 25,680 48,251 Other electric revenues (b) 107,599 130,269 47,887 8,093 37,329 Non-customer revenues (c) 9,434 15,564 7,671 4,414 1,157 Total electric revenues 1,776,267 3,252,826 983,713 464,773 1,146,931 Natural gas — 44,498 — 68,418 — Total operating revenues $1,776,267 $3,297,324 $983,713 $533,191 $1,146,931 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (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) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Asset Retirement Obligations As

Asset Retirement Obligations Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2019
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units. In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million
Entergy Arkansas [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units. In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million
Entergy Louisiana [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units. In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million
Entergy Mississippi [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units. In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million
Entergy New Orleans [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units. In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million
Entergy Texas [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units. In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million
System Energy [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units. In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million

Leases Leases

Leases Leases	9 Months Ended
	Sep. 30, 2019
Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU 2016-02, “Leases (Topic 842),” effective January 1, 2019. The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. Concurrent with the implementation of ASU 2016-02, Entergy implemented ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” which provided Entergy the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard, and ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” which intended to simplify the transition requirement giving Entergy the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period. In implementing these ASUs, Entergy elected the options provided in both ASU 2018-01 and ASU 2018-11. This accounting was applied to all lease agreements using the modified retrospective method, which required an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date, and when implemented with ASU 2018-11, allowed Entergy to recognize the leased assets and liabilities on its balance sheet beginning on January 1, 2019 without restating prior periods. In adopting the standard, in January 2019 Entergy recognized right-of-use assets and corresponding lease liabilities totaling approximately $263 million , including $59 million for Entergy Arkansas, $51 million for Entergy Louisiana, $26 million for Entergy Mississippi, $7 million for Entergy New Orleans, and $16 million for Entergy Texas. Implementation of the standards had no material effect on consolidated net income; therefore, no adjustment to retained earnings was recorded. The adoption of the standards had no effect on cash flows. General As of September 30, 2019, Entergy and the Registrant Subsidiaries held operating and financing leases for fleet vehicles used in operations, real estate, and aircraft. Excluded from this are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases. Leases have remaining terms of one year to 52 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications which would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor; however, due to the nature of the agreements and Entergy’s continuing relationship with the lessor, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the three months ended September 30, 2019: (In Thousands) Operating lease cost $16,086 Financing lease cost: Amortization of right-of-use assets $2,945 Interest on lease liabilities $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019: (In Thousands) Operating lease cost $47,061 Financing lease cost: Amortization of right-of-use assets $10,837 Interest on lease liabilities $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by Entergy for leases with all costs included within operating activities on the Consolidated Statements of Cash Flows, except for the financing lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,306 $3,003 $1,752 $349 $1,074 Financing lease cost: Amortization of right-of-use assets $621 $1,014 $369 $178 $335 Interest on lease liabilities $105 $161 $65 $29 $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $9,724 $8,854 $5,220 $1,058 $3,135 Financing lease cost: Amortization of right-of-use assets $2,448 $4,014 $1,408 $696 $965 Interest on lease liabilities $408 $612 $241 $114 $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the financing lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at September 30, 2019 are $236 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $49,503 $34,248 $18,149 $3,894 $13,074 Financing leases $11,094 $16,795 $6,994 $2,913 $5,515 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019: (In Thousands) Current liabilities: Operating leases $52,348 Financing leases $11,482 Non-current liabilities: Operating leases $184,404 Financing leases $53,252 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,662 $9,969 $6,137 $1,138 $3,427 Financing leases $2,600 $3,860 $1,473 $626 $1,252 Non-current liabilities: Operating leases $38,881 $24,289 $12,254 $2,755 $9,689 Financing leases $8,665 $12,925 $5,521 $2,286 $4,221 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms: Operating leases 5.10 Financing leases 6.79 Weighted average discount rate: Operating leases 3.91 % Financing leases 4.67 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.09 4.28 4.65 3.99 4.49 Financing leases 5.44 5.41 5.41 5.72 5.25 Weighted average discount rate: Operating leases 3.75 % 3.74 % 3.77 % 3.94 % 3.86 % Financing leases 3.75 % 3.75 % 3.71 % 3.93 % 3.84 % Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $16,088 $3,608 2020 59,965 13,521 2021 53,791 11,973 2022 45,391 10,775 2023 35,050 9,664 Years thereafter 56,906 26,889 Minimum lease payments 267,191 76,430 Less: amount representing interest 30,438 11,696 Present value of net minimum lease payments $236,753 $64,734 Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $3,168 $2,863 $1,968 $332 $1,022 2020 11,756 10,518 6,066 1,196 4,014 2021 9,911 8,787 4,937 939 3,279 2022 7,613 6,068 3,503 659 2,338 2023 6,341 4,079 1,376 497 1,994 Years thereafter 16,421 4,702 2,642 729 2,193 Minimum lease payments 55,210 37,017 20,492 4,352 14,840 Less: amount representing interest 5,667 2,759 2,101 459 1,724 Present value of net minimum lease payments $49,543 $34,258 $18,391 $3,893 $13,116 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $713 $1,135 $429 $204 $375 2020 2,654 4,191 1,655 660 1,364 2021 2,258 3,536 1,490 549 1,171 2022 1,969 3,096 1,297 499 965 2023 1,728 2,635 1,078 451 827 Years thereafter 2,905 3,818 1,740 881 1,316 Minimum lease payments 12,227 18,411 7,689 3,244 6,018 Less: amount representing interest 961 1,626 695 332 545 Present value of net minimum lease payments $11,266 $16,785 $6,994 $2,912 $5,473 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases. In accordance with ASU 2018-11, below is the lease disclosure from Note 10 to the financial statements in the Form 10-K. General As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere): Year Operating Leases Capital Leases (In Thousands) 2019 $94,043 $2,887 2020 82,191 2,887 2021 75,147 2,887 2022 60,808 2,887 2023 47,391 2,887 Years thereafter 88,004 16,117 Minimum lease payments 447,584 30,552 Less: Amount representing interest — 8,555 Present value of net minimum lease payments $447,584 $21,997 Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $47.8 million in 2018, $53.1 million in 2017, and $44.4 million in 2016. As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $20,421 $25,970 $9,344 $2,493 $5,744 2020 13,918 21,681 8,763 2,349 4,431 2021 11,931 19,514 7,186 1,901 3,625 2022 9,458 15,756 5,675 1,314 2,218 2023 7,782 12,092 2,946 1,043 1,561 Years thereafter 23,297 22,003 4,417 2,323 2,726 Minimum lease payments $86,807 $117,016 $38,331 $11,423 $20,305 Rental Expenses Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2018 $6.2 $20.2 $4.6 $2.5 $3.1 $1.9 2017 $7.5 $23.0 $5.6 $2.5 $3.4 $2.2 2016 $8.0 $17.8 $4.0 $0.9 $2.8 $1.6 In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment. Railcar operating lease payments were $2.8 million in 2018, $4 million in 2017, and $3.4 million in 2016 for Entergy Arkansas and $0.4 million in 2018, $0.3 million in 2017, and $0.3 million in 2016 for Entergy Louisiana. Oil tank facilities lease payments for Entergy Mississippi were $0.1 million in 2018, $1.6 million in 2017, and $1.6 million in 2016. On January 1, 2019, Entergy implemented ASU No. 2016-02, “Leases (Topic 842)” along with the practical expedients provided by ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” and ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements.” See Note 1 to the financial statements in the Form 10-K for further discussion of ASU No. 2016-02. Power Purchase Agreements As of December 31, 2018, Entergy Texas had a power purchase agreement that is accounted for as an operating lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory treatment. The minimum lease payments under the power purchase agreement are as follows: Year Entergy Texas (a) Entergy (In Thousands) 2019 $31,159 $31,159 2020 31,876 31,876 2021 32,609 32,609 2022 10,180 10,180 Minimum lease payments $105,824 $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas. Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was $30.5 million in 2018, $34.1 million in 2017, and $26.1 million in 2016. Sales and Leaseback Transactions Waterford 3 Lease Obligation In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million . The leases were scheduled to expire in July 2017. Entergy Louisiana was required to report the sale-leaseback as a financing transaction in its financial statements. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. The purchase was accomplished in a two-step transaction in which Entergy Louisiana first acquired the equity participant’s beneficial interest in the leased assets, followed by a termination of the leases and transfer of the leased assets to Entergy Louisiana when the outstanding lessor debt is paid. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana continued to make payments on the lessor debt that remained outstanding and which matured in January 2017. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt was equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017. Throughout the term of the lease, Entergy Louisiana had accrued a liability for the amount it expected to pay to retain the use of the undivided interests in Waterford 3 at the end of the lease term. Since the sale-leaseback transaction was accounted for as a financing transaction, the accrual of this liability was accounted for as additional interest expense. As of December 2015, the balance of this liability was $62.7 million . Upon entering into the agreement to purchase the equity participant’s beneficial interest in the undivided interests, Entergy Louisiana reduced the balance of the liability to $60 million , and recorded the $2.7 million difference as a credit to interest expense. The $60 million remaining liability was eliminated upon payment of the cash portion of the purchase price in 2016. As of December 31, 2016, Entergy Louisiana, in connection with the Waterford 3 lease obligation, had a future minimum lease payment (reflecting an interest rate of 8.09% ) of $57.5 million , including $2.3 million in interest, due January 2017 that was recorded as long-term debt. In February 2017 the leases were terminated and the leased assets were conveyed to Entergy Louisiana. Grand Gulf Lease Obligations In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million . The initial term of the leases expired in July 2015. System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation. However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term. The amount was a net regulatory liability of $55.6 million as of December 31, 2018 and 2017. As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352
Entergy Arkansas [Member]
Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU 2016-02, “Leases (Topic 842),” effective January 1, 2019. The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. Concurrent with the implementation of ASU 2016-02, Entergy implemented ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” which provided Entergy the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard, and ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” which intended to simplify the transition requirement giving Entergy the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period. In implementing these ASUs, Entergy elected the options provided in both ASU 2018-01 and ASU 2018-11. This accounting was applied to all lease agreements using the modified retrospective method, which required an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date, and when implemented with ASU 2018-11, allowed Entergy to recognize the leased assets and liabilities on its balance sheet beginning on January 1, 2019 without restating prior periods. In adopting the standard, in January 2019 Entergy recognized right-of-use assets and corresponding lease liabilities totaling approximately $263 million , including $59 million for Entergy Arkansas, $51 million for Entergy Louisiana, $26 million for Entergy Mississippi, $7 million for Entergy New Orleans, and $16 million for Entergy Texas. Implementation of the standards had no material effect on consolidated net income; therefore, no adjustment to retained earnings was recorded. The adoption of the standards had no effect on cash flows. General As of September 30, 2019, Entergy and the Registrant Subsidiaries held operating and financing leases for fleet vehicles used in operations, real estate, and aircraft. Excluded from this are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases. Leases have remaining terms of one year to 52 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications which would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor; however, due to the nature of the agreements and Entergy’s continuing relationship with the lessor, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the three months ended September 30, 2019: (In Thousands) Operating lease cost $16,086 Financing lease cost: Amortization of right-of-use assets $2,945 Interest on lease liabilities $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019: (In Thousands) Operating lease cost $47,061 Financing lease cost: Amortization of right-of-use assets $10,837 Interest on lease liabilities $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by Entergy for leases with all costs included within operating activities on the Consolidated Statements of Cash Flows, except for the financing lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,306 $3,003 $1,752 $349 $1,074 Financing lease cost: Amortization of right-of-use assets $621 $1,014 $369 $178 $335 Interest on lease liabilities $105 $161 $65 $29 $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $9,724 $8,854 $5,220 $1,058 $3,135 Financing lease cost: Amortization of right-of-use assets $2,448 $4,014 $1,408 $696 $965 Interest on lease liabilities $408 $612 $241 $114 $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the financing lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at September 30, 2019 are $236 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $49,503 $34,248 $18,149 $3,894 $13,074 Financing leases $11,094 $16,795 $6,994 $2,913 $5,515 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019: (In Thousands) Current liabilities: Operating leases $52,348 Financing leases $11,482 Non-current liabilities: Operating leases $184,404 Financing leases $53,252 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,662 $9,969 $6,137 $1,138 $3,427 Financing leases $2,600 $3,860 $1,473 $626 $1,252 Non-current liabilities: Operating leases $38,881 $24,289 $12,254 $2,755 $9,689 Financing leases $8,665 $12,925 $5,521 $2,286 $4,221 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms: Operating leases 5.10 Financing leases 6.79 Weighted average discount rate: Operating leases 3.91 % Financing leases 4.67 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.09 4.28 4.65 3.99 4.49 Financing leases 5.44 5.41 5.41 5.72 5.25 Weighted average discount rate: Operating leases 3.75 % 3.74 % 3.77 % 3.94 % 3.86 % Financing leases 3.75 % 3.75 % 3.71 % 3.93 % 3.84 % Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $16,088 $3,608 2020 59,965 13,521 2021 53,791 11,973 2022 45,391 10,775 2023 35,050 9,664 Years thereafter 56,906 26,889 Minimum lease payments 267,191 76,430 Less: amount representing interest 30,438 11,696 Present value of net minimum lease payments $236,753 $64,734 Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $3,168 $2,863 $1,968 $332 $1,022 2020 11,756 10,518 6,066 1,196 4,014 2021 9,911 8,787 4,937 939 3,279 2022 7,613 6,068 3,503 659 2,338 2023 6,341 4,079 1,376 497 1,994 Years thereafter 16,421 4,702 2,642 729 2,193 Minimum lease payments 55,210 37,017 20,492 4,352 14,840 Less: amount representing interest 5,667 2,759 2,101 459 1,724 Present value of net minimum lease payments $49,543 $34,258 $18,391 $3,893 $13,116 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $713 $1,135 $429 $204 $375 2020 2,654 4,191 1,655 660 1,364 2021 2,258 3,536 1,490 549 1,171 2022 1,969 3,096 1,297 499 965 2023 1,728 2,635 1,078 451 827 Years thereafter 2,905 3,818 1,740 881 1,316 Minimum lease payments 12,227 18,411 7,689 3,244 6,018 Less: amount representing interest 961 1,626 695 332 545 Present value of net minimum lease payments $11,266 $16,785 $6,994 $2,912 $5,473 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases. In accordance with ASU 2018-11, below is the lease disclosure from Note 10 to the financial statements in the Form 10-K. General As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere): Year Operating Leases Capital Leases (In Thousands) 2019 $94,043 $2,887 2020 82,191 2,887 2021 75,147 2,887 2022 60,808 2,887 2023 47,391 2,887 Years thereafter 88,004 16,117 Minimum lease payments 447,584 30,552 Less: Amount representing interest — 8,555 Present value of net minimum lease payments $447,584 $21,997 Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $47.8 million in 2018, $53.1 million in 2017, and $44.4 million in 2016. As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $20,421 $25,970 $9,344 $2,493 $5,744 2020 13,918 21,681 8,763 2,349 4,431 2021 11,931 19,514 7,186 1,901 3,625 2022 9,458 15,756 5,675 1,314 2,218 2023 7,782 12,092 2,946 1,043 1,561 Years thereafter 23,297 22,003 4,417 2,323 2,726 Minimum lease payments $86,807 $117,016 $38,331 $11,423 $20,305 Rental Expenses Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2018 $6.2 $20.2 $4.6 $2.5 $3.1 $1.9 2017 $7.5 $23.0 $5.6 $2.5 $3.4 $2.2 2016 $8.0 $17.8 $4.0 $0.9 $2.8 $1.6 In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment. Railcar operating lease payments were $2.8 million in 2018, $4 million in 2017, and $3.4 million in 2016 for Entergy Arkansas and $0.4 million in 2018, $0.3 million in 2017, and $0.3 million in 2016 for Entergy Louisiana. Oil tank facilities lease payments for Entergy Mississippi were $0.1 million in 2018, $1.6 million in 2017, and $1.6 million in 2016. On January 1, 2019, Entergy implemented ASU No. 2016-02, “Leases (Topic 842)” along with the practical expedients provided by ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” and ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements.” See Note 1 to the financial statements in the Form 10-K for further discussion of ASU No. 2016-02. Power Purchase Agreements As of December 31, 2018, Entergy Texas had a power purchase agreement that is accounted for as an operating lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory treatment. The minimum lease payments under the power purchase agreement are as follows: Year Entergy Texas (a) Entergy (In Thousands) 2019 $31,159 $31,159 2020 31,876 31,876 2021 32,609 32,609 2022 10,180 10,180 Minimum lease payments $105,824 $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas. Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was $30.5 million in 2018, $34.1 million in 2017, and $26.1 million in 2016. Sales and Leaseback Transactions Waterford 3 Lease Obligation In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million . The leases were scheduled to expire in July 2017. Entergy Louisiana was required to report the sale-leaseback as a financing transaction in its financial statements. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. The purchase was accomplished in a two-step transaction in which Entergy Louisiana first acquired the equity participant’s beneficial interest in the leased assets, followed by a termination of the leases and transfer of the leased assets to Entergy Louisiana when the outstanding lessor debt is paid. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana continued to make payments on the lessor debt that remained outstanding and which matured in January 2017. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt was equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017. Throughout the term of the lease, Entergy Louisiana had accrued a liability for the amount it expected to pay to retain the use of the undivided interests in Waterford 3 at the end of the lease term. Since the sale-leaseback transaction was accounted for as a financing transaction, the accrual of this liability was accounted for as additional interest expense. As of December 2015, the balance of this liability was $62.7 million . Upon entering into the agreement to purchase the equity participant’s beneficial interest in the undivided interests, Entergy Louisiana reduced the balance of the liability to $60 million , and recorded the $2.7 million difference as a credit to interest expense. The $60 million remaining liability was eliminated upon payment of the cash portion of the purchase price in 2016. As of December 31, 2016, Entergy Louisiana, in connection with the Waterford 3 lease obligation, had a future minimum lease payment (reflecting an interest rate of 8.09% ) of $57.5 million , including $2.3 million in interest, due January 2017 that was recorded as long-term debt. In February 2017 the leases were terminated and the leased assets were conveyed to Entergy Louisiana. Grand Gulf Lease Obligations In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million . The initial term of the leases expired in July 2015. System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation. However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term. The amount was a net regulatory liability of $55.6 million as of December 31, 2018 and 2017. As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352
Entergy Louisiana [Member]
Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU 2016-02, “Leases (Topic 842),” effective January 1, 2019. The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. Concurrent with the implementation of ASU 2016-02, Entergy implemented ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” which provided Entergy the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard, and ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” which intended to simplify the transition requirement giving Entergy the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period. In implementing these ASUs, Entergy elected the options provided in both ASU 2018-01 and ASU 2018-11. This accounting was applied to all lease agreements using the modified retrospective method, which required an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date, and when implemented with ASU 2018-11, allowed Entergy to recognize the leased assets and liabilities on its balance sheet beginning on January 1, 2019 without restating prior periods. In adopting the standard, in January 2019 Entergy recognized right-of-use assets and corresponding lease liabilities totaling approximately $263 million , including $59 million for Entergy Arkansas, $51 million for Entergy Louisiana, $26 million for Entergy Mississippi, $7 million for Entergy New Orleans, and $16 million for Entergy Texas. Implementation of the standards had no material effect on consolidated net income; therefore, no adjustment to retained earnings was recorded. The adoption of the standards had no effect on cash flows. General As of September 30, 2019, Entergy and the Registrant Subsidiaries held operating and financing leases for fleet vehicles used in operations, real estate, and aircraft. Excluded from this are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases. Leases have remaining terms of one year to 52 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications which would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor; however, due to the nature of the agreements and Entergy’s continuing relationship with the lessor, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the three months ended September 30, 2019: (In Thousands) Operating lease cost $16,086 Financing lease cost: Amortization of right-of-use assets $2,945 Interest on lease liabilities $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019: (In Thousands) Operating lease cost $47,061 Financing lease cost: Amortization of right-of-use assets $10,837 Interest on lease liabilities $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by Entergy for leases with all costs included within operating activities on the Consolidated Statements of Cash Flows, except for the financing lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,306 $3,003 $1,752 $349 $1,074 Financing lease cost: Amortization of right-of-use assets $621 $1,014 $369 $178 $335 Interest on lease liabilities $105 $161 $65 $29 $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $9,724 $8,854 $5,220 $1,058 $3,135 Financing lease cost: Amortization of right-of-use assets $2,448 $4,014 $1,408 $696 $965 Interest on lease liabilities $408 $612 $241 $114 $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the financing lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at September 30, 2019 are $236 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $49,503 $34,248 $18,149 $3,894 $13,074 Financing leases $11,094 $16,795 $6,994 $2,913 $5,515 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019: (In Thousands) Current liabilities: Operating leases $52,348 Financing leases $11,482 Non-current liabilities: Operating leases $184,404 Financing leases $53,252 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,662 $9,969 $6,137 $1,138 $3,427 Financing leases $2,600 $3,860 $1,473 $626 $1,252 Non-current liabilities: Operating leases $38,881 $24,289 $12,254 $2,755 $9,689 Financing leases $8,665 $12,925 $5,521 $2,286 $4,221 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms: Operating leases 5.10 Financing leases 6.79 Weighted average discount rate: Operating leases 3.91 % Financing leases 4.67 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.09 4.28 4.65 3.99 4.49 Financing leases 5.44 5.41 5.41 5.72 5.25 Weighted average discount rate: Operating leases 3.75 % 3.74 % 3.77 % 3.94 % 3.86 % Financing leases 3.75 % 3.75 % 3.71 % 3.93 % 3.84 % Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $16,088 $3,608 2020 59,965 13,521 2021 53,791 11,973 2022 45,391 10,775 2023 35,050 9,664 Years thereafter 56,906 26,889 Minimum lease payments 267,191 76,430 Less: amount representing interest 30,438 11,696 Present value of net minimum lease payments $236,753 $64,734 Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $3,168 $2,863 $1,968 $332 $1,022 2020 11,756 10,518 6,066 1,196 4,014 2021 9,911 8,787 4,937 939 3,279 2022 7,613 6,068 3,503 659 2,338 2023 6,341 4,079 1,376 497 1,994 Years thereafter 16,421 4,702 2,642 729 2,193 Minimum lease payments 55,210 37,017 20,492 4,352 14,840 Less: amount representing interest 5,667 2,759 2,101 459 1,724 Present value of net minimum lease payments $49,543 $34,258 $18,391 $3,893 $13,116 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $713 $1,135 $429 $204 $375 2020 2,654 4,191 1,655 660 1,364 2021 2,258 3,536 1,490 549 1,171 2022 1,969 3,096 1,297 499 965 2023 1,728 2,635 1,078 451 827 Years thereafter 2,905 3,818 1,740 881 1,316 Minimum lease payments 12,227 18,411 7,689 3,244 6,018 Less: amount representing interest 961 1,626 695 332 545 Present value of net minimum lease payments $11,266 $16,785 $6,994 $2,912 $5,473 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases. In accordance with ASU 2018-11, below is the lease disclosure from Note 10 to the financial statements in the Form 10-K. General As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere): Year Operating Leases Capital Leases (In Thousands) 2019 $94,043 $2,887 2020 82,191 2,887 2021 75,147 2,887 2022 60,808 2,887 2023 47,391 2,887 Years thereafter 88,004 16,117 Minimum lease payments 447,584 30,552 Less: Amount representing interest — 8,555 Present value of net minimum lease payments $447,584 $21,997 Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $47.8 million in 2018, $53.1 million in 2017, and $44.4 million in 2016. As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $20,421 $25,970 $9,344 $2,493 $5,744 2020 13,918 21,681 8,763 2,349 4,431 2021 11,931 19,514 7,186 1,901 3,625 2022 9,458 15,756 5,675 1,314 2,218 2023 7,782 12,092 2,946 1,043 1,561 Years thereafter 23,297 22,003 4,417 2,323 2,726 Minimum lease payments $86,807 $117,016 $38,331 $11,423 $20,305 Rental Expenses Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2018 $6.2 $20.2 $4.6 $2.5 $3.1 $1.9 2017 $7.5 $23.0 $5.6 $2.5 $3.4 $2.2 2016 $8.0 $17.8 $4.0 $0.9 $2.8 $1.6 In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment. Railcar operating lease payments were $2.8 million in 2018, $4 million in 2017, and $3.4 million in 2016 for Entergy Arkansas and $0.4 million in 2018, $0.3 million in 2017, and $0.3 million in 2016 for Entergy Louisiana. Oil tank facilities lease payments for Entergy Mississippi were $0.1 million in 2018, $1.6 million in 2017, and $1.6 million in 2016. On January 1, 2019, Entergy implemented ASU No. 2016-02, “Leases (Topic 842)” along with the practical expedients provided by ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” and ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements.” See Note 1 to the financial statements in the Form 10-K for further discussion of ASU No. 2016-02. Power Purchase Agreements As of December 31, 2018, Entergy Texas had a power purchase agreement that is accounted for as an operating lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory treatment. The minimum lease payments under the power purchase agreement are as follows: Year Entergy Texas (a) Entergy (In Thousands) 2019 $31,159 $31,159 2020 31,876 31,876 2021 32,609 32,609 2022 10,180 10,180 Minimum lease payments $105,824 $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas. Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was $30.5 million in 2018, $34.1 million in 2017, and $26.1 million in 2016. Sales and Leaseback Transactions Waterford 3 Lease Obligation In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million . The leases were scheduled to expire in July 2017. Entergy Louisiana was required to report the sale-leaseback as a financing transaction in its financial statements. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. The purchase was accomplished in a two-step transaction in which Entergy Louisiana first acquired the equity participant’s beneficial interest in the leased assets, followed by a termination of the leases and transfer of the leased assets to Entergy Louisiana when the outstanding lessor debt is paid. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana continued to make payments on the lessor debt that remained outstanding and which matured in January 2017. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt was equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017. Throughout the term of the lease, Entergy Louisiana had accrued a liability for the amount it expected to pay to retain the use of the undivided interests in Waterford 3 at the end of the lease term. Since the sale-leaseback transaction was accounted for as a financing transaction, the accrual of this liability was accounted for as additional interest expense. As of December 2015, the balance of this liability was $62.7 million . Upon entering into the agreement to purchase the equity participant’s beneficial interest in the undivided interests, Entergy Louisiana reduced the balance of the liability to $60 million , and recorded the $2.7 million difference as a credit to interest expense. The $60 million remaining liability was eliminated upon payment of the cash portion of the purchase price in 2016. As of December 31, 2016, Entergy Louisiana, in connection with the Waterford 3 lease obligation, had a future minimum lease payment (reflecting an interest rate of 8.09% ) of $57.5 million , including $2.3 million in interest, due January 2017 that was recorded as long-term debt. In February 2017 the leases were terminated and the leased assets were conveyed to Entergy Louisiana. Grand Gulf Lease Obligations In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million . The initial term of the leases expired in July 2015. System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation. However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term. The amount was a net regulatory liability of $55.6 million as of December 31, 2018 and 2017. As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352
Entergy Mississippi [Member]
Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU 2016-02, “Leases (Topic 842),” effective January 1, 2019. The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. Concurrent with the implementation of ASU 2016-02, Entergy implemented ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” which provided Entergy the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard, and ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” which intended to simplify the transition requirement giving Entergy the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period. In implementing these ASUs, Entergy elected the options provided in both ASU 2018-01 and ASU 2018-11. This accounting was applied to all lease agreements using the modified retrospective method, which required an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date, and when implemented with ASU 2018-11, allowed Entergy to recognize the leased assets and liabilities on its balance sheet beginning on January 1, 2019 without restating prior periods. In adopting the standard, in January 2019 Entergy recognized right-of-use assets and corresponding lease liabilities totaling approximately $263 million , including $59 million for Entergy Arkansas, $51 million for Entergy Louisiana, $26 million for Entergy Mississippi, $7 million for Entergy New Orleans, and $16 million for Entergy Texas. Implementation of the standards had no material effect on consolidated net income; therefore, no adjustment to retained earnings was recorded. The adoption of the standards had no effect on cash flows. General As of September 30, 2019, Entergy and the Registrant Subsidiaries held operating and financing leases for fleet vehicles used in operations, real estate, and aircraft. Excluded from this are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases. Leases have remaining terms of one year to 52 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications which would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor; however, due to the nature of the agreements and Entergy’s continuing relationship with the lessor, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the three months ended September 30, 2019: (In Thousands) Operating lease cost $16,086 Financing lease cost: Amortization of right-of-use assets $2,945 Interest on lease liabilities $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019: (In Thousands) Operating lease cost $47,061 Financing lease cost: Amortization of right-of-use assets $10,837 Interest on lease liabilities $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by Entergy for leases with all costs included within operating activities on the Consolidated Statements of Cash Flows, except for the financing lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,306 $3,003 $1,752 $349 $1,074 Financing lease cost: Amortization of right-of-use assets $621 $1,014 $369 $178 $335 Interest on lease liabilities $105 $161 $65 $29 $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $9,724 $8,854 $5,220 $1,058 $3,135 Financing lease cost: Amortization of right-of-use assets $2,448 $4,014 $1,408 $696 $965 Interest on lease liabilities $408 $612 $241 $114 $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the financing lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at September 30, 2019 are $236 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $49,503 $34,248 $18,149 $3,894 $13,074 Financing leases $11,094 $16,795 $6,994 $2,913 $5,515 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019: (In Thousands) Current liabilities: Operating leases $52,348 Financing leases $11,482 Non-current liabilities: Operating leases $184,404 Financing leases $53,252 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,662 $9,969 $6,137 $1,138 $3,427 Financing leases $2,600 $3,860 $1,473 $626 $1,252 Non-current liabilities: Operating leases $38,881 $24,289 $12,254 $2,755 $9,689 Financing leases $8,665 $12,925 $5,521 $2,286 $4,221 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms: Operating leases 5.10 Financing leases 6.79 Weighted average discount rate: Operating leases 3.91 % Financing leases 4.67 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.09 4.28 4.65 3.99 4.49 Financing leases 5.44 5.41 5.41 5.72 5.25 Weighted average discount rate: Operating leases 3.75 % 3.74 % 3.77 % 3.94 % 3.86 % Financing leases 3.75 % 3.75 % 3.71 % 3.93 % 3.84 % Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $16,088 $3,608 2020 59,965 13,521 2021 53,791 11,973 2022 45,391 10,775 2023 35,050 9,664 Years thereafter 56,906 26,889 Minimum lease payments 267,191 76,430 Less: amount representing interest 30,438 11,696 Present value of net minimum lease payments $236,753 $64,734 Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $3,168 $2,863 $1,968 $332 $1,022 2020 11,756 10,518 6,066 1,196 4,014 2021 9,911 8,787 4,937 939 3,279 2022 7,613 6,068 3,503 659 2,338 2023 6,341 4,079 1,376 497 1,994 Years thereafter 16,421 4,702 2,642 729 2,193 Minimum lease payments 55,210 37,017 20,492 4,352 14,840 Less: amount representing interest 5,667 2,759 2,101 459 1,724 Present value of net minimum lease payments $49,543 $34,258 $18,391 $3,893 $13,116 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $713 $1,135 $429 $204 $375 2020 2,654 4,191 1,655 660 1,364 2021 2,258 3,536 1,490 549 1,171 2022 1,969 3,096 1,297 499 965 2023 1,728 2,635 1,078 451 827 Years thereafter 2,905 3,818 1,740 881 1,316 Minimum lease payments 12,227 18,411 7,689 3,244 6,018 Less: amount representing interest 961 1,626 695 332 545 Present value of net minimum lease payments $11,266 $16,785 $6,994 $2,912 $5,473 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases. In accordance with ASU 2018-11, below is the lease disclosure from Note 10 to the financial statements in the Form 10-K. General As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere): Year Operating Leases Capital Leases (In Thousands) 2019 $94,043 $2,887 2020 82,191 2,887 2021 75,147 2,887 2022 60,808 2,887 2023 47,391 2,887 Years thereafter 88,004 16,117 Minimum lease payments 447,584 30,552 Less: Amount representing interest — 8,555 Present value of net minimum lease payments $447,584 $21,997 Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $47.8 million in 2018, $53.1 million in 2017, and $44.4 million in 2016. As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $20,421 $25,970 $9,344 $2,493 $5,744 2020 13,918 21,681 8,763 2,349 4,431 2021 11,931 19,514 7,186 1,901 3,625 2022 9,458 15,756 5,675 1,314 2,218 2023 7,782 12,092 2,946 1,043 1,561 Years thereafter 23,297 22,003 4,417 2,323 2,726 Minimum lease payments $86,807 $117,016 $38,331 $11,423 $20,305 Rental Expenses Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2018 $6.2 $20.2 $4.6 $2.5 $3.1 $1.9 2017 $7.5 $23.0 $5.6 $2.5 $3.4 $2.2 2016 $8.0 $17.8 $4.0 $0.9 $2.8 $1.6 In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment. Railcar operating lease payments were $2.8 million in 2018, $4 million in 2017, and $3.4 million in 2016 for Entergy Arkansas and $0.4 million in 2018, $0.3 million in 2017, and $0.3 million in 2016 for Entergy Louisiana. Oil tank facilities lease payments for Entergy Mississippi were $0.1 million in 2018, $1.6 million in 2017, and $1.6 million in 2016. On January 1, 2019, Entergy implemented ASU No. 2016-02, “Leases (Topic 842)” along with the practical expedients provided by ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” and ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements.” See Note 1 to the financial statements in the Form 10-K for further discussion of ASU No. 2016-02. Power Purchase Agreements As of December 31, 2018, Entergy Texas had a power purchase agreement that is accounted for as an operating lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory treatment. The minimum lease payments under the power purchase agreement are as follows: Year Entergy Texas (a) Entergy (In Thousands) 2019 $31,159 $31,159 2020 31,876 31,876 2021 32,609 32,609 2022 10,180 10,180 Minimum lease payments $105,824 $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas. Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was $30.5 million in 2018, $34.1 million in 2017, and $26.1 million in 2016. Sales and Leaseback Transactions Waterford 3 Lease Obligation In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million . The leases were scheduled to expire in July 2017. Entergy Louisiana was required to report the sale-leaseback as a financing transaction in its financial statements. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. The purchase was accomplished in a two-step transaction in which Entergy Louisiana first acquired the equity participant’s beneficial interest in the leased assets, followed by a termination of the leases and transfer of the leased assets to Entergy Louisiana when the outstanding lessor debt is paid. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana continued to make payments on the lessor debt that remained outstanding and which matured in January 2017. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt was equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017. Throughout the term of the lease, Entergy Louisiana had accrued a liability for the amount it expected to pay to retain the use of the undivided interests in Waterford 3 at the end of the lease term. Since the sale-leaseback transaction was accounted for as a financing transaction, the accrual of this liability was accounted for as additional interest expense. As of December 2015, the balance of this liability was $62.7 million . Upon entering into the agreement to purchase the equity participant’s beneficial interest in the undivided interests, Entergy Louisiana reduced the balance of the liability to $60 million , and recorded the $2.7 million difference as a credit to interest expense. The $60 million remaining liability was eliminated upon payment of the cash portion of the purchase price in 2016. As of December 31, 2016, Entergy Louisiana, in connection with the Waterford 3 lease obligation, had a future minimum lease payment (reflecting an interest rate of 8.09% ) of $57.5 million , including $2.3 million in interest, due January 2017 that was recorded as long-term debt. In February 2017 the leases were terminated and the leased assets were conveyed to Entergy Louisiana. Grand Gulf Lease Obligations In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million . The initial term of the leases expired in July 2015. System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation. However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term. The amount was a net regulatory liability of $55.6 million as of December 31, 2018 and 2017. As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352
Entergy New Orleans [Member]
Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU 2016-02, “Leases (Topic 842),” effective January 1, 2019. The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. Concurrent with the implementation of ASU 2016-02, Entergy implemented ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” which provided Entergy the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard, and ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” which intended to simplify the transition requirement giving Entergy the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period. In implementing these ASUs, Entergy elected the options provided in both ASU 2018-01 and ASU 2018-11. This accounting was applied to all lease agreements using the modified retrospective method, which required an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date, and when implemented with ASU 2018-11, allowed Entergy to recognize the leased assets and liabilities on its balance sheet beginning on January 1, 2019 without restating prior periods. In adopting the standard, in January 2019 Entergy recognized right-of-use assets and corresponding lease liabilities totaling approximately $263 million , including $59 million for Entergy Arkansas, $51 million for Entergy Louisiana, $26 million for Entergy Mississippi, $7 million for Entergy New Orleans, and $16 million for Entergy Texas. Implementation of the standards had no material effect on consolidated net income; therefore, no adjustment to retained earnings was recorded. The adoption of the standards had no effect on cash flows. General As of September 30, 2019, Entergy and the Registrant Subsidiaries held operating and financing leases for fleet vehicles used in operations, real estate, and aircraft. Excluded from this are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases. Leases have remaining terms of one year to 52 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications which would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor; however, due to the nature of the agreements and Entergy’s continuing relationship with the lessor, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the three months ended September 30, 2019: (In Thousands) Operating lease cost $16,086 Financing lease cost: Amortization of right-of-use assets $2,945 Interest on lease liabilities $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019: (In Thousands) Operating lease cost $47,061 Financing lease cost: Amortization of right-of-use assets $10,837 Interest on lease liabilities $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by Entergy for leases with all costs included within operating activities on the Consolidated Statements of Cash Flows, except for the financing lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,306 $3,003 $1,752 $349 $1,074 Financing lease cost: Amortization of right-of-use assets $621 $1,014 $369 $178 $335 Interest on lease liabilities $105 $161 $65 $29 $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $9,724 $8,854 $5,220 $1,058 $3,135 Financing lease cost: Amortization of right-of-use assets $2,448 $4,014 $1,408 $696 $965 Interest on lease liabilities $408 $612 $241 $114 $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the financing lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at September 30, 2019 are $236 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $49,503 $34,248 $18,149 $3,894 $13,074 Financing leases $11,094 $16,795 $6,994 $2,913 $5,515 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019: (In Thousands) Current liabilities: Operating leases $52,348 Financing leases $11,482 Non-current liabilities: Operating leases $184,404 Financing leases $53,252 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,662 $9,969 $6,137 $1,138 $3,427 Financing leases $2,600 $3,860 $1,473 $626 $1,252 Non-current liabilities: Operating leases $38,881 $24,289 $12,254 $2,755 $9,689 Financing leases $8,665 $12,925 $5,521 $2,286 $4,221 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms: Operating leases 5.10 Financing leases 6.79 Weighted average discount rate: Operating leases 3.91 % Financing leases 4.67 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.09 4.28 4.65 3.99 4.49 Financing leases 5.44 5.41 5.41 5.72 5.25 Weighted average discount rate: Operating leases 3.75 % 3.74 % 3.77 % 3.94 % 3.86 % Financing leases 3.75 % 3.75 % 3.71 % 3.93 % 3.84 % Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $16,088 $3,608 2020 59,965 13,521 2021 53,791 11,973 2022 45,391 10,775 2023 35,050 9,664 Years thereafter 56,906 26,889 Minimum lease payments 267,191 76,430 Less: amount representing interest 30,438 11,696 Present value of net minimum lease payments $236,753 $64,734 Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $3,168 $2,863 $1,968 $332 $1,022 2020 11,756 10,518 6,066 1,196 4,014 2021 9,911 8,787 4,937 939 3,279 2022 7,613 6,068 3,503 659 2,338 2023 6,341 4,079 1,376 497 1,994 Years thereafter 16,421 4,702 2,642 729 2,193 Minimum lease payments 55,210 37,017 20,492 4,352 14,840 Less: amount representing interest 5,667 2,759 2,101 459 1,724 Present value of net minimum lease payments $49,543 $34,258 $18,391 $3,893 $13,116 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $713 $1,135 $429 $204 $375 2020 2,654 4,191 1,655 660 1,364 2021 2,258 3,536 1,490 549 1,171 2022 1,969 3,096 1,297 499 965 2023 1,728 2,635 1,078 451 827 Years thereafter 2,905 3,818 1,740 881 1,316 Minimum lease payments 12,227 18,411 7,689 3,244 6,018 Less: amount representing interest 961 1,626 695 332 545 Present value of net minimum lease payments $11,266 $16,785 $6,994 $2,912 $5,473 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases. In accordance with ASU 2018-11, below is the lease disclosure from Note 10 to the financial statements in the Form 10-K. General As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere): Year Operating Leases Capital Leases (In Thousands) 2019 $94,043 $2,887 2020 82,191 2,887 2021 75,147 2,887 2022 60,808 2,887 2023 47,391 2,887 Years thereafter 88,004 16,117 Minimum lease payments 447,584 30,552 Less: Amount representing interest — 8,555 Present value of net minimum lease payments $447,584 $21,997 Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $47.8 million in 2018, $53.1 million in 2017, and $44.4 million in 2016. As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $20,421 $25,970 $9,344 $2,493 $5,744 2020 13,918 21,681 8,763 2,349 4,431 2021 11,931 19,514 7,186 1,901 3,625 2022 9,458 15,756 5,675 1,314 2,218 2023 7,782 12,092 2,946 1,043 1,561 Years thereafter 23,297 22,003 4,417 2,323 2,726 Minimum lease payments $86,807 $117,016 $38,331 $11,423 $20,305 Rental Expenses Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2018 $6.2 $20.2 $4.6 $2.5 $3.1 $1.9 2017 $7.5 $23.0 $5.6 $2.5 $3.4 $2.2 2016 $8.0 $17.8 $4.0 $0.9 $2.8 $1.6 In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment. Railcar operating lease payments were $2.8 million in 2018, $4 million in 2017, and $3.4 million in 2016 for Entergy Arkansas and $0.4 million in 2018, $0.3 million in 2017, and $0.3 million in 2016 for Entergy Louisiana. Oil tank facilities lease payments for Entergy Mississippi were $0.1 million in 2018, $1.6 million in 2017, and $1.6 million in 2016. On January 1, 2019, Entergy implemented ASU No. 2016-02, “Leases (Topic 842)” along with the practical expedients provided by ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” and ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements.” See Note 1 to the financial statements in the Form 10-K for further discussion of ASU No. 2016-02. Power Purchase Agreements As of December 31, 2018, Entergy Texas had a power purchase agreement that is accounted for as an operating lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory treatment. The minimum lease payments under the power purchase agreement are as follows: Year Entergy Texas (a) Entergy (In Thousands) 2019 $31,159 $31,159 2020 31,876 31,876 2021 32,609 32,609 2022 10,180 10,180 Minimum lease payments $105,824 $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas. Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was $30.5 million in 2018, $34.1 million in 2017, and $26.1 million in 2016. Sales and Leaseback Transactions Waterford 3 Lease Obligation In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million . The leases were scheduled to expire in July 2017. Entergy Louisiana was required to report the sale-leaseback as a financing transaction in its financial statements. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. The purchase was accomplished in a two-step transaction in which Entergy Louisiana first acquired the equity participant’s beneficial interest in the leased assets, followed by a termination of the leases and transfer of the leased assets to Entergy Louisiana when the outstanding lessor debt is paid. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana continued to make payments on the lessor debt that remained outstanding and which matured in January 2017. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt was equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017. Throughout the term of the lease, Entergy Louisiana had accrued a liability for the amount it expected to pay to retain the use of the undivided interests in Waterford 3 at the end of the lease term. Since the sale-leaseback transaction was accounted for as a financing transaction, the accrual of this liability was accounted for as additional interest expense. As of December 2015, the balance of this liability was $62.7 million . Upon entering into the agreement to purchase the equity participant’s beneficial interest in the undivided interests, Entergy Louisiana reduced the balance of the liability to $60 million , and recorded the $2.7 million difference as a credit to interest expense. The $60 million remaining liability was eliminated upon payment of the cash portion of the purchase price in 2016. As of December 31, 2016, Entergy Louisiana, in connection with the Waterford 3 lease obligation, had a future minimum lease payment (reflecting an interest rate of 8.09% ) of $57.5 million , including $2.3 million in interest, due January 2017 that was recorded as long-term debt. In February 2017 the leases were terminated and the leased assets were conveyed to Entergy Louisiana. Grand Gulf Lease Obligations In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million . The initial term of the leases expired in July 2015. System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation. However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term. The amount was a net regulatory liability of $55.6 million as of December 31, 2018 and 2017. As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352
Entergy Texas [Member]
Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU 2016-02, “Leases (Topic 842),” effective January 1, 2019. The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. Concurrent with the implementation of ASU 2016-02, Entergy implemented ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” which provided Entergy the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard, and ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” which intended to simplify the transition requirement giving Entergy the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period. In implementing these ASUs, Entergy elected the options provided in both ASU 2018-01 and ASU 2018-11. This accounting was applied to all lease agreements using the modified retrospective method, which required an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date, and when implemented with ASU 2018-11, allowed Entergy to recognize the leased assets and liabilities on its balance sheet beginning on January 1, 2019 without restating prior periods. In adopting the standard, in January 2019 Entergy recognized right-of-use assets and corresponding lease liabilities totaling approximately $263 million , including $59 million for Entergy Arkansas, $51 million for Entergy Louisiana, $26 million for Entergy Mississippi, $7 million for Entergy New Orleans, and $16 million for Entergy Texas. Implementation of the standards had no material effect on consolidated net income; therefore, no adjustment to retained earnings was recorded. The adoption of the standards had no effect on cash flows. General As of September 30, 2019, Entergy and the Registrant Subsidiaries held operating and financing leases for fleet vehicles used in operations, real estate, and aircraft. Excluded from this are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases. Leases have remaining terms of one year to 52 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications which would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor; however, due to the nature of the agreements and Entergy’s continuing relationship with the lessor, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the three months ended September 30, 2019: (In Thousands) Operating lease cost $16,086 Financing lease cost: Amortization of right-of-use assets $2,945 Interest on lease liabilities $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019: (In Thousands) Operating lease cost $47,061 Financing lease cost: Amortization of right-of-use assets $10,837 Interest on lease liabilities $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by Entergy for leases with all costs included within operating activities on the Consolidated Statements of Cash Flows, except for the financing lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,306 $3,003 $1,752 $349 $1,074 Financing lease cost: Amortization of right-of-use assets $621 $1,014 $369 $178 $335 Interest on lease liabilities $105 $161 $65 $29 $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $9,724 $8,854 $5,220 $1,058 $3,135 Financing lease cost: Amortization of right-of-use assets $2,448 $4,014 $1,408 $696 $965 Interest on lease liabilities $408 $612 $241 $114 $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the financing lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at September 30, 2019 are $236 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $49,503 $34,248 $18,149 $3,894 $13,074 Financing leases $11,094 $16,795 $6,994 $2,913 $5,515 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019: (In Thousands) Current liabilities: Operating leases $52,348 Financing leases $11,482 Non-current liabilities: Operating leases $184,404 Financing leases $53,252 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,662 $9,969 $6,137 $1,138 $3,427 Financing leases $2,600 $3,860 $1,473 $626 $1,252 Non-current liabilities: Operating leases $38,881 $24,289 $12,254 $2,755 $9,689 Financing leases $8,665 $12,925 $5,521 $2,286 $4,221 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms: Operating leases 5.10 Financing leases 6.79 Weighted average discount rate: Operating leases 3.91 % Financing leases 4.67 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.09 4.28 4.65 3.99 4.49 Financing leases 5.44 5.41 5.41 5.72 5.25 Weighted average discount rate: Operating leases 3.75 % 3.74 % 3.77 % 3.94 % 3.86 % Financing leases 3.75 % 3.75 % 3.71 % 3.93 % 3.84 % Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $16,088 $3,608 2020 59,965 13,521 2021 53,791 11,973 2022 45,391 10,775 2023 35,050 9,664 Years thereafter 56,906 26,889 Minimum lease payments 267,191 76,430 Less: amount representing interest 30,438 11,696 Present value of net minimum lease payments $236,753 $64,734 Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $3,168 $2,863 $1,968 $332 $1,022 2020 11,756 10,518 6,066 1,196 4,014 2021 9,911 8,787 4,937 939 3,279 2022 7,613 6,068 3,503 659 2,338 2023 6,341 4,079 1,376 497 1,994 Years thereafter 16,421 4,702 2,642 729 2,193 Minimum lease payments 55,210 37,017 20,492 4,352 14,840 Less: amount representing interest 5,667 2,759 2,101 459 1,724 Present value of net minimum lease payments $49,543 $34,258 $18,391 $3,893 $13,116 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $713 $1,135 $429 $204 $375 2020 2,654 4,191 1,655 660 1,364 2021 2,258 3,536 1,490 549 1,171 2022 1,969 3,096 1,297 499 965 2023 1,728 2,635 1,078 451 827 Years thereafter 2,905 3,818 1,740 881 1,316 Minimum lease payments 12,227 18,411 7,689 3,244 6,018 Less: amount representing interest 961 1,626 695 332 545 Present value of net minimum lease payments $11,266 $16,785 $6,994 $2,912 $5,473 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases. In accordance with ASU 2018-11, below is the lease disclosure from Note 10 to the financial statements in the Form 10-K. General As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere): Year Operating Leases Capital Leases (In Thousands) 2019 $94,043 $2,887 2020 82,191 2,887 2021 75,147 2,887 2022 60,808 2,887 2023 47,391 2,887 Years thereafter 88,004 16,117 Minimum lease payments 447,584 30,552 Less: Amount representing interest — 8,555 Present value of net minimum lease payments $447,584 $21,997 Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $47.8 million in 2018, $53.1 million in 2017, and $44.4 million in 2016. As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $20,421 $25,970 $9,344 $2,493 $5,744 2020 13,918 21,681 8,763 2,349 4,431 2021 11,931 19,514 7,186 1,901 3,625 2022 9,458 15,756 5,675 1,314 2,218 2023 7,782 12,092 2,946 1,043 1,561 Years thereafter 23,297 22,003 4,417 2,323 2,726 Minimum lease payments $86,807 $117,016 $38,331 $11,423 $20,305 Rental Expenses Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2018 $6.2 $20.2 $4.6 $2.5 $3.1 $1.9 2017 $7.5 $23.0 $5.6 $2.5 $3.4 $2.2 2016 $8.0 $17.8 $4.0 $0.9 $2.8 $1.6 In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment. Railcar operating lease payments were $2.8 million in 2018, $4 million in 2017, and $3.4 million in 2016 for Entergy Arkansas and $0.4 million in 2018, $0.3 million in 2017, and $0.3 million in 2016 for Entergy Louisiana. Oil tank facilities lease payments for Entergy Mississippi were $0.1 million in 2018, $1.6 million in 2017, and $1.6 million in 2016. On January 1, 2019, Entergy implemented ASU No. 2016-02, “Leases (Topic 842)” along with the practical expedients provided by ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” and ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements.” See Note 1 to the financial statements in the Form 10-K for further discussion of ASU No. 2016-02. Power Purchase Agreements As of December 31, 2018, Entergy Texas had a power purchase agreement that is accounted for as an operating lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory treatment. The minimum lease payments under the power purchase agreement are as follows: Year Entergy Texas (a) Entergy (In Thousands) 2019 $31,159 $31,159 2020 31,876 31,876 2021 32,609 32,609 2022 10,180 10,180 Minimum lease payments $105,824 $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas. Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was $30.5 million in 2018, $34.1 million in 2017, and $26.1 million in 2016. Sales and Leaseback Transactions Waterford 3 Lease Obligation In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million . The leases were scheduled to expire in July 2017. Entergy Louisiana was required to report the sale-leaseback as a financing transaction in its financial statements. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. The purchase was accomplished in a two-step transaction in which Entergy Louisiana first acquired the equity participant’s beneficial interest in the leased assets, followed by a termination of the leases and transfer of the leased assets to Entergy Louisiana when the outstanding lessor debt is paid. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana continued to make payments on the lessor debt that remained outstanding and which matured in January 2017. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt was equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017. Throughout the term of the lease, Entergy Louisiana had accrued a liability for the amount it expected to pay to retain the use of the undivided interests in Waterford 3 at the end of the lease term. Since the sale-leaseback transaction was accounted for as a financing transaction, the accrual of this liability was accounted for as additional interest expense. As of December 2015, the balance of this liability was $62.7 million . Upon entering into the agreement to purchase the equity participant’s beneficial interest in the undivided interests, Entergy Louisiana reduced the balance of the liability to $60 million , and recorded the $2.7 million difference as a credit to interest expense. The $60 million remaining liability was eliminated upon payment of the cash portion of the purchase price in 2016. As of December 31, 2016, Entergy Louisiana, in connection with the Waterford 3 lease obligation, had a future minimum lease payment (reflecting an interest rate of 8.09% ) of $57.5 million , including $2.3 million in interest, due January 2017 that was recorded as long-term debt. In February 2017 the leases were terminated and the leased assets were conveyed to Entergy Louisiana. Grand Gulf Lease Obligations In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million . The initial term of the leases expired in July 2015. System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation. However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term. The amount was a net regulatory liability of $55.6 million as of December 31, 2018 and 2017. As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352
System Energy [Member]
Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU 2016-02, “Leases (Topic 842),” effective January 1, 2019. The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. Concurrent with the implementation of ASU 2016-02, Entergy implemented ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” which provided Entergy the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard, and ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” which intended to simplify the transition requirement giving Entergy the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period. In implementing these ASUs, Entergy elected the options provided in both ASU 2018-01 and ASU 2018-11. This accounting was applied to all lease agreements using the modified retrospective method, which required an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date, and when implemented with ASU 2018-11, allowed Entergy to recognize the leased assets and liabilities on its balance sheet beginning on January 1, 2019 without restating prior periods. In adopting the standard, in January 2019 Entergy recognized right-of-use assets and corresponding lease liabilities totaling approximately $263 million , including $59 million for Entergy Arkansas, $51 million for Entergy Louisiana, $26 million for Entergy Mississippi, $7 million for Entergy New Orleans, and $16 million for Entergy Texas. Implementation of the standards had no material effect on consolidated net income; therefore, no adjustment to retained earnings was recorded. The adoption of the standards had no effect on cash flows. General As of September 30, 2019, Entergy and the Registrant Subsidiaries held operating and financing leases for fleet vehicles used in operations, real estate, and aircraft. Excluded from this are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases. Leases have remaining terms of one year to 52 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications which would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor; however, due to the nature of the agreements and Entergy’s continuing relationship with the lessor, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the three months ended September 30, 2019: (In Thousands) Operating lease cost $16,086 Financing lease cost: Amortization of right-of-use assets $2,945 Interest on lease liabilities $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019: (In Thousands) Operating lease cost $47,061 Financing lease cost: Amortization of right-of-use assets $10,837 Interest on lease liabilities $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by Entergy for leases with all costs included within operating activities on the Consolidated Statements of Cash Flows, except for the financing lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,306 $3,003 $1,752 $349 $1,074 Financing lease cost: Amortization of right-of-use assets $621 $1,014 $369 $178 $335 Interest on lease liabilities $105 $161 $65 $29 $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $9,724 $8,854 $5,220 $1,058 $3,135 Financing lease cost: Amortization of right-of-use assets $2,448 $4,014 $1,408 $696 $965 Interest on lease liabilities $408 $612 $241 $114 $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the financing lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at September 30, 2019 are $236 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $49,503 $34,248 $18,149 $3,894 $13,074 Financing leases $11,094 $16,795 $6,994 $2,913 $5,515 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019: (In Thousands) Current liabilities: Operating leases $52,348 Financing leases $11,482 Non-current liabilities: Operating leases $184,404 Financing leases $53,252 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,662 $9,969 $6,137 $1,138 $3,427 Financing leases $2,600 $3,860 $1,473 $626 $1,252 Non-current liabilities: Operating leases $38,881 $24,289 $12,254 $2,755 $9,689 Financing leases $8,665 $12,925 $5,521 $2,286 $4,221 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms: Operating leases 5.10 Financing leases 6.79 Weighted average discount rate: Operating leases 3.91 % Financing leases 4.67 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.09 4.28 4.65 3.99 4.49 Financing leases 5.44 5.41 5.41 5.72 5.25 Weighted average discount rate: Operating leases 3.75 % 3.74 % 3.77 % 3.94 % 3.86 % Financing leases 3.75 % 3.75 % 3.71 % 3.93 % 3.84 % Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $16,088 $3,608 2020 59,965 13,521 2021 53,791 11,973 2022 45,391 10,775 2023 35,050 9,664 Years thereafter 56,906 26,889 Minimum lease payments 267,191 76,430 Less: amount representing interest 30,438 11,696 Present value of net minimum lease payments $236,753 $64,734 Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $3,168 $2,863 $1,968 $332 $1,022 2020 11,756 10,518 6,066 1,196 4,014 2021 9,911 8,787 4,937 939 3,279 2022 7,613 6,068 3,503 659 2,338 2023 6,341 4,079 1,376 497 1,994 Years thereafter 16,421 4,702 2,642 729 2,193 Minimum lease payments 55,210 37,017 20,492 4,352 14,840 Less: amount representing interest 5,667 2,759 2,101 459 1,724 Present value of net minimum lease payments $49,543 $34,258 $18,391 $3,893 $13,116 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $713 $1,135 $429 $204 $375 2020 2,654 4,191 1,655 660 1,364 2021 2,258 3,536 1,490 549 1,171 2022 1,969 3,096 1,297 499 965 2023 1,728 2,635 1,078 451 827 Years thereafter 2,905 3,818 1,740 881 1,316 Minimum lease payments 12,227 18,411 7,689 3,244 6,018 Less: amount representing interest 961 1,626 695 332 545 Present value of net minimum lease payments $11,266 $16,785 $6,994 $2,912 $5,473 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases. In accordance with ASU 2018-11, below is the lease disclosure from Note 10 to the financial statements in the Form 10-K. General As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere): Year Operating Leases Capital Leases (In Thousands) 2019 $94,043 $2,887 2020 82,191 2,887 2021 75,147 2,887 2022 60,808 2,887 2023 47,391 2,887 Years thereafter 88,004 16,117 Minimum lease payments 447,584 30,552 Less: Amount representing interest — 8,555 Present value of net minimum lease payments $447,584 $21,997 Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $47.8 million in 2018, $53.1 million in 2017, and $44.4 million in 2016. As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $20,421 $25,970 $9,344 $2,493 $5,744 2020 13,918 21,681 8,763 2,349 4,431 2021 11,931 19,514 7,186 1,901 3,625 2022 9,458 15,756 5,675 1,314 2,218 2023 7,782 12,092 2,946 1,043 1,561 Years thereafter 23,297 22,003 4,417 2,323 2,726 Minimum lease payments $86,807 $117,016 $38,331 $11,423 $20,305 Rental Expenses Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2018 $6.2 $20.2 $4.6 $2.5 $3.1 $1.9 2017 $7.5 $23.0 $5.6 $2.5 $3.4 $2.2 2016 $8.0 $17.8 $4.0 $0.9 $2.8 $1.6 In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment. Railcar operating lease payments were $2.8 million in 2018, $4 million in 2017, and $3.4 million in 2016 for Entergy Arkansas and $0.4 million in 2018, $0.3 million in 2017, and $0.3 million in 2016 for Entergy Louisiana. Oil tank facilities lease payments for Entergy Mississippi were $0.1 million in 2018, $1.6 million in 2017, and $1.6 million in 2016. On January 1, 2019, Entergy implemented ASU No. 2016-02, “Leases (Topic 842)” along with the practical expedients provided by ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” and ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements.” See Note 1 to the financial statements in the Form 10-K for further discussion of ASU No. 2016-02. Power Purchase Agreements As of December 31, 2018, Entergy Texas had a power purchase agreement that is accounted for as an operating lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory treatment. The minimum lease payments under the power purchase agreement are as follows: Year Entergy Texas (a) Entergy (In Thousands) 2019 $31,159 $31,159 2020 31,876 31,876 2021 32,609 32,609 2022 10,180 10,180 Minimum lease payments $105,824 $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas. Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was $30.5 million in 2018, $34.1 million in 2017, and $26.1 million in 2016. Sales and Leaseback Transactions Waterford 3 Lease Obligation In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million . The leases were scheduled to expire in July 2017. Entergy Louisiana was required to report the sale-leaseback as a financing transaction in its financial statements. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. The purchase was accomplished in a two-step transaction in which Entergy Louisiana first acquired the equity participant’s beneficial interest in the leased assets, followed by a termination of the leases and transfer of the leased assets to Entergy Louisiana when the outstanding lessor debt is paid. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana continued to make payments on the lessor debt that remained outstanding and which matured in January 2017. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt was equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017. Throughout the term of the lease, Entergy Louisiana had accrued a liability for the amount it expected to pay to retain the use of the undivided interests in Waterford 3 at the end of the lease term. Since the sale-leaseback transaction was accounted for as a financing transaction, the accrual of this liability was accounted for as additional interest expense. As of December 2015, the balance of this liability was $62.7 million . Upon entering into the agreement to purchase the equity participant’s beneficial interest in the undivided interests, Entergy Louisiana reduced the balance of the liability to $60 million , and recorded the $2.7 million difference as a credit to interest expense. The $60 million remaining liability was eliminated upon payment of the cash portion of the purchase price in 2016. As of December 31, 2016, Entergy Louisiana, in connection with the Waterford 3 lease obligation, had a future minimum lease payment (reflecting an interest rate of 8.09% ) of $57.5 million , including $2.3 million in interest, due January 2017 that was recorded as long-term debt. In February 2017 the leases were terminated and the leased assets were conveyed to Entergy Louisiana. Grand Gulf Lease Obligations In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million . The initial term of the leases expired in July 2015. System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation. However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term. The amount was a net regulatory liability of $55.6 million as of December 31, 2018 and 2017. As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352

Dispositions Dispositions

Dispositions Dispositions	9 Months Ended
	Sep. 30, 2019
Business Acquisition [Line Items]
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	DISPOSITIONS (Entergy Corporation) Vermont Yankee As discussed in Note 14 to the financial statements in the Form 10-K, in January 2019, Entergy transferred 100% of the membership interests in Entergy Nuclear Vermont Yankee, LLC, the owner of the Vermont Yankee plant, to a subsidiary of NorthStar. Entergy Nuclear Vermont Yankee had an outstanding credit facility that was used to pay for dry fuel storage costs. This credit facility was guaranteed by Entergy Corporation. Vermont Yankee Asset Retirement Management, LLC, a subsidiary of Entergy, assumed the obligations under the credit facility. At the closing of the transaction, NorthStar caused Entergy Nuclear Vermont Yankee, renamed NorthStar Vermont Yankee, to issue a $139 million promissory note to Vermont Yankee Asset Retirement Management. The amount of the note included the balance outstanding on the credit facility, as well as borrowing fees and costs incurred by Entergy in connection with the credit facility. Upon closing of the transaction in January 2019, the Vermont Yankee decommissioning trust, along with the decommissioning obligation for the plant, was transferred to NorthStar. The Vermont Yankee spent fuel disposal contract was assigned to NorthStar as part of the transaction. The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. The transaction also resulted in other charges of $5.4 million ( $4.2 million net-of-tax) in the first quarter 2019. Pilgrim In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in Entergy Nuclear Generation Company, the owner of the Pilgrim plant. In August 2019 the NRC approved the sale of the plant to Holtec. The transaction closed in August 2019 for a purchase price of $1,000 (subject to adjustments for net liabilities and other amounts). The sale included the transfer of the Pilgrim nuclear decommissioning trust and obligation for spent fuel management and plant decommissioning. The transaction resulted in a loss of $191 million ( $156 million net-of-tax) in the third quarter 2019. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $1,030 million and the disposition-date fair value of the asset retirement obligation was $837 million . The transaction also included property, plant, and equipment with a net book value of zero , materials and supplies, and prepaid assets.

Rate And Regulatory Matters Rat

Rate And Regulatory Matters Rate and Regulatory Matters (Tables)	9 Months Ended
	Sep. 30, 2019
Entergy Arkansas [Member] | FERC December 2015 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)
Entergy Arkansas [Member] | FERC May 2018 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The filing shows the additional following payments and receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6
Entergy Louisiana [Member] | FERC December 2015 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)
Entergy Louisiana [Member] | FERC May 2018 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The filing shows the additional following payments and receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6
Entergy Mississippi [Member] | FERC December 2015 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)
Entergy Mississippi [Member] | FERC May 2018 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The filing shows the additional following payments and receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6
Entergy New Orleans [Member] | FERC December 2015 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)
Entergy New Orleans [Member] | FERC May 2018 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The filing shows the additional following payments and receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6
Entergy Texas [Member] | FERC December 2015 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)
Entergy Texas [Member] | FERC May 2018 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The filing shows the additional following payments and receipts among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6

Equity (Tables)

Equity (Tables)	9 Months Ended
	Sep. 30, 2019
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 September 30, 2019 2018 (In Millions, Except Per Share Data) Income Shares $/share Income Shares $/share Basic earnings per share Net income attributable to Entergy Corporation $365.2 198.9 $1.84 $536.4 181.0 $2.96 Average dilutive effect of: Stock options 0.7 (0.01 ) 0.4 (0.01 ) Other equity plans 0.9 (0.01 ) 0.8 (0.01 ) Equity forwards — — 1.5 (0.02 ) Diluted earnings per share $365.2 200.5 $1.82 $536.4 183.7 $2.92 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.1 million for the three months ended September 30, 2018 . For the Nine Months Ended September 30, 2019 2018 (In Millions, Except Per Share Data) Income Shares $/share Income Shares $/share Basic earnings per share Net income attributable to Entergy Corporation $856.2 193.9 $4.42 $914.6 180.8 $5.06 Average dilutive effect of: Stock options 0.5 (0.01 ) 0.3 (0.01 ) Other equity plans 0.7 (0.02 ) 0.7 (0.01 ) Equity forwards 0.6 (0.01 ) 0.9 (0.03 ) Diluted earnings per share $856.2 195.7 $4.38 $914.6 182.7 $5.01 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.2 million for the nine months ended September 30, 2019 and approximately 1.1 million for the nine months ended September 30, 2018 .
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 September 30, 2019 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, July 1, 2019 $51,736 ($508,876 ) $26,736 ($430,404 ) Other comprehensive income (loss) before reclassifications (5,190 ) — 8,350 3,160 Amounts reclassified from accumulated other comprehensive income (loss) (14,913 ) 25,464 (3,079 ) 7,472 Net other comprehensive income (loss) for the period (20,103 ) 25,464 5,271 10,632 Ending balance, September 30, 2019 $31,633 ($483,412 ) $32,007 ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, July 1, 2018 ($14,874 ) ($589,926 ) ($8,842 ) ($613,642 ) Other comprehensive income (loss) before reclassifications (40,401 ) — (7,173 ) (47,574 ) Amounts reclassified from accumulated other comprehensive income (loss) 8,397 15,265 5,428 29,090 Net other comprehensive income (loss) for the period (32,004 ) 15,265 (1,745 ) (18,484 ) Ending balance, September 30, 2018 ($46,878 ) ($574,661 ) ($10,587 ) ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2019 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Ending balance, December 31, 2018 ($23,135 ) ($531,922 ) ($2,116 ) ($557,173 ) Implementation of accounting standards (7,685 ) — 879 (6,806 ) Beginning balance, January 1, 2019 ($30,820 ) ($531,922 ) ($1,237 ) ($563,979 ) Other comprehensive income (loss) before reclassifications 122,481 — 37,724 160,205 Amounts reclassified from accumulated other comprehensive income (loss) (60,028 ) 48,510 (4,480 ) (15,998 ) Net other comprehensive income (loss) for the period 62,453 48,510 33,244 144,207 Ending balance, September 30, 2019 $31,633 ($483,412 ) $32,007 ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Ending balance, December 31, 2017 ($37,477 ) ($531,099 ) $545,045 ($23,531 ) Implementation of accounting standards — — (632,617 ) (632,617 ) Beginning balance, January 1, 2018 ($37,477 ) ($531,099 ) ($87,572 ) ($656,148 ) Other comprehensive income (loss) before reclassifications (31,816 ) — (50,958 ) (82,774 ) Amounts reclassified from accumulated other comprehensive income (loss) 30,171 47,404 13,716 91,291 Net other comprehensive income (loss) for the period (1,645 ) 47,404 (37,242 ) 8,517 Reclassification pursuant to ASU 2018-02 (7,756 ) (90,966 ) 114,227 15,505 Ending balance, September 30, 2018 ($46,878 ) ($574,661 ) ($10,587 ) ($632,126 )
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 September 30, 2019 and 2018 are as follows: Amounts reclassified Income Statement Location 2019 2018 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $18,925 ($10,566 ) Competitive business operating revenues Interest rate swaps (48 ) (63 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 18,877 (10,629 ) (3,964 ) 2,232 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $14,913 ($8,397 ) Pension and other postretirement liabilities Amortization of prior-service credit $5,325 $5,425 (a) Amortization of loss (20,919 ) (24,740 ) (a) Settlement loss (16,630 ) (76 ) (a) Total amortization (32,224 ) (19,391 ) 6,760 4,126 Income taxes Total amortization (net of tax) ($25,464 ) ($15,265 ) Net unrealized investment gain (loss) Realized gain (loss) $4,872 ($8,589 ) Interest and investment income (1,793 ) 3,161 Income taxes Total realized investment gain (loss) (net of tax) $3,079 ($5,428 ) Total reclassifications for the period (net of tax) ($7,472 ) ($29,090 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the nine months ended September 30, 2019 and 2018 are as follows: Amounts reclassified from AOCI Income Statement Location 2019 2018 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $76,129 ($37,913 ) Competitive business operating revenues Interest rate swaps (145 ) (278 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 75,984 (38,191 ) (15,956 ) 8,020 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $60,028 ($30,171 ) Pension and other postretirement liabilities Amortization of prior-service credit $15,977 $16,278 (a) Amortization of loss (58,888 ) (74,503 ) (a) Settlement loss (18,685 ) (2,098 ) (a) Total amortization (61,596 ) (60,323 ) 13,086 12,919 Income taxes Total amortization (net of tax) ($48,510 ) ($47,404 ) Net unrealized investment gain (loss) Realized gain (loss) $7,088 ($21,703 ) Interest and investment income (2,608 ) 7,987 Income taxes Total realized investment gain (loss) (net of tax) $4,480 ($13,716 ) Total reclassifications for the period (net of tax) $15,998 ($91,291 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.
Entergy Louisiana [Member]
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2019 and 2018: Pension and Other 2019 2018 (In Thousands) Beginning balance, July 1, ($8,091 ) ($57,451 ) Amounts reclassified from accumulated other (969 ) (500 ) Net other comprehensive income (loss) for the period (969 ) (500 ) Ending balance, September 30, ($9,060 ) ($57,951 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2019 and 2018: Pension and Other 2019 2018 (In Thousands) Beginning balance, January 1, ($6,153 ) ($46,400 ) Amounts reclassified from accumulated other (2,907 ) (1,502 ) Net other comprehensive income (loss) for the period (2,907 ) (1,502 ) Reclassification pursuant to ASU 2018-02 — (10,049 ) Ending balance, September 30, ($9,060 ) ($57,951 )
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 September 30, 2019 and 2018 are as follows: Amounts reclassified Income Statement Location 2019 2018 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,837 $1,934 (a) Amortization of loss (526 ) (1,257 ) (a) Total amortization 1,311 677 (342 ) (177 ) Income taxes Total amortization (net of tax) 969 500 Total reclassifications for the period (net of tax) $969 $500 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the nine months ended September 30, 2019 and 2018 are as follows: Amounts reclassified Income Statement Location 2019 2018 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,511 $5,802 (a) Amortization of loss (1,578 ) (3,770 ) (a) Total amortization 3,933 2,032 (1,026 ) (530 ) Income taxes Total amortization (net of tax) 2,907 1,502 Total reclassifications for the period (net of tax) $2,907 $1,502 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.

Revolving Credit Facilities, _2

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2019
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 September 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $155 $6 $3,339
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2019 Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.17% $— $— Entergy Arkansas September 2024 $150 million (c) 3.17% $— $— Entergy Louisiana September 2024 $350 million (c) 3.17% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.54% $— $— Entergy Mississippi May 2020 $35 million (d) 3.54% $— $— Entergy Mississippi May 2020 $10 million (d) 3.54% $— $— Entergy New Orleans November 2021 $25 million (c) 3.32% $— $0.8 million Entergy Texas September 2024 $150 million (c) 3.54% $— $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 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 September 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $11.7 million Entergy Mississippi $65 million 0.70% $8.1 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $26.2 million (a) As of September 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (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 $— Entergy New Orleans $150 $46 Entergy Texas $200 $— 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 September 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.41% $30.3 Entergy Louisiana River Bend VIE September 2021 $105 3.37% $84.3 Entergy Louisiana Waterford VIE September 2021 $105 3.41% $65.5 System Energy VIE September 2021 $120 3.42% $53.6 (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 are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.42% Series J due April 2021 $100 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 September 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,458,026 $18,628,268 Entergy Arkansas $3,538,384 $3,621,073 Entergy Louisiana $7,344,160 $8,038,675 Entergy Mississippi $1,469,454 $1,586,199 Entergy New Orleans $478,619 $522,688 Entergy Texas $1,938,303 $2,128,842 System Energy $570,001 $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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, 2018 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,168,312 $15,880,239 Entergy Arkansas $3,225,759 $3,002,627 Entergy Louisiana $6,805,768 $6,834,134 Entergy Mississippi $1,325,750 $1,276,452 Entergy New Orleans $483,704 $491,569 Entergy Texas $1,513,735 $1,528,828 System Energy $630,750 $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Arkansas [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2019 Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.17% $— $— Entergy Arkansas September 2024 $150 million (c) 3.17% $— $— Entergy Louisiana September 2024 $350 million (c) 3.17% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.54% $— $— Entergy Mississippi May 2020 $35 million (d) 3.54% $— $— Entergy Mississippi May 2020 $10 million (d) 3.54% $— $— Entergy New Orleans November 2021 $25 million (c) 3.32% $— $0.8 million Entergy Texas September 2024 $150 million (c) 3.54% $— $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 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 September 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $11.7 million Entergy Mississippi $65 million 0.70% $8.1 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $26.2 million (a) As of September 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (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 $— Entergy New Orleans $150 $46 Entergy Texas $200 $— 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 September 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.41% $30.3 Entergy Louisiana River Bend VIE September 2021 $105 3.37% $84.3 Entergy Louisiana Waterford VIE September 2021 $105 3.41% $65.5 System Energy VIE September 2021 $120 3.42% $53.6 (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 are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.42% Series J due April 2021 $100 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 September 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,458,026 $18,628,268 Entergy Arkansas $3,538,384 $3,621,073 Entergy Louisiana $7,344,160 $8,038,675 Entergy Mississippi $1,469,454 $1,586,199 Entergy New Orleans $478,619 $522,688 Entergy Texas $1,938,303 $2,128,842 System Energy $570,001 $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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, 2018 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,168,312 $15,880,239 Entergy Arkansas $3,225,759 $3,002,627 Entergy Louisiana $6,805,768 $6,834,134 Entergy Mississippi $1,325,750 $1,276,452 Entergy New Orleans $483,704 $491,569 Entergy Texas $1,513,735 $1,528,828 System Energy $630,750 $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Louisiana [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2019 Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.17% $— $— Entergy Arkansas September 2024 $150 million (c) 3.17% $— $— Entergy Louisiana September 2024 $350 million (c) 3.17% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.54% $— $— Entergy Mississippi May 2020 $35 million (d) 3.54% $— $— Entergy Mississippi May 2020 $10 million (d) 3.54% $— $— Entergy New Orleans November 2021 $25 million (c) 3.32% $— $0.8 million Entergy Texas September 2024 $150 million (c) 3.54% $— $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 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 September 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $11.7 million Entergy Mississippi $65 million 0.70% $8.1 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $26.2 million (a) As of September 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (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 $— Entergy New Orleans $150 $46 Entergy Texas $200 $— 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 September 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.41% $30.3 Entergy Louisiana River Bend VIE September 2021 $105 3.37% $84.3 Entergy Louisiana Waterford VIE September 2021 $105 3.41% $65.5 System Energy VIE September 2021 $120 3.42% $53.6 (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 are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.42% Series J due April 2021 $100 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 September 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,458,026 $18,628,268 Entergy Arkansas $3,538,384 $3,621,073 Entergy Louisiana $7,344,160 $8,038,675 Entergy Mississippi $1,469,454 $1,586,199 Entergy New Orleans $478,619 $522,688 Entergy Texas $1,938,303 $2,128,842 System Energy $570,001 $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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, 2018 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,168,312 $15,880,239 Entergy Arkansas $3,225,759 $3,002,627 Entergy Louisiana $6,805,768 $6,834,134 Entergy Mississippi $1,325,750 $1,276,452 Entergy New Orleans $483,704 $491,569 Entergy Texas $1,513,735 $1,528,828 System Energy $630,750 $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Mississippi [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2019 Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.17% $— $— Entergy Arkansas September 2024 $150 million (c) 3.17% $— $— Entergy Louisiana September 2024 $350 million (c) 3.17% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.54% $— $— Entergy Mississippi May 2020 $35 million (d) 3.54% $— $— Entergy Mississippi May 2020 $10 million (d) 3.54% $— $— Entergy New Orleans November 2021 $25 million (c) 3.32% $— $0.8 million Entergy Texas September 2024 $150 million (c) 3.54% $— $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 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 September 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $11.7 million Entergy Mississippi $65 million 0.70% $8.1 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $26.2 million (a) As of September 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (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 $— Entergy New Orleans $150 $46 Entergy Texas $200 $— 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 September 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,458,026 $18,628,268 Entergy Arkansas $3,538,384 $3,621,073 Entergy Louisiana $7,344,160 $8,038,675 Entergy Mississippi $1,469,454 $1,586,199 Entergy New Orleans $478,619 $522,688 Entergy Texas $1,938,303 $2,128,842 System Energy $570,001 $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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, 2018 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,168,312 $15,880,239 Entergy Arkansas $3,225,759 $3,002,627 Entergy Louisiana $6,805,768 $6,834,134 Entergy Mississippi $1,325,750 $1,276,452 Entergy New Orleans $483,704 $491,569 Entergy Texas $1,513,735 $1,528,828 System Energy $630,750 $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy New Orleans [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2019 Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.17% $— $— Entergy Arkansas September 2024 $150 million (c) 3.17% $— $— Entergy Louisiana September 2024 $350 million (c) 3.17% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.54% $— $— Entergy Mississippi May 2020 $35 million (d) 3.54% $— $— Entergy Mississippi May 2020 $10 million (d) 3.54% $— $— Entergy New Orleans November 2021 $25 million (c) 3.32% $— $0.8 million Entergy Texas September 2024 $150 million (c) 3.54% $— $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 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 September 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $11.7 million Entergy Mississippi $65 million 0.70% $8.1 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $26.2 million (a) As of September 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (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 $— Entergy New Orleans $150 $46 Entergy Texas $200 $— 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 September 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,458,026 $18,628,268 Entergy Arkansas $3,538,384 $3,621,073 Entergy Louisiana $7,344,160 $8,038,675 Entergy Mississippi $1,469,454 $1,586,199 Entergy New Orleans $478,619 $522,688 Entergy Texas $1,938,303 $2,128,842 System Energy $570,001 $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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, 2018 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,168,312 $15,880,239 Entergy Arkansas $3,225,759 $3,002,627 Entergy Louisiana $6,805,768 $6,834,134 Entergy Mississippi $1,325,750 $1,276,452 Entergy New Orleans $483,704 $491,569 Entergy Texas $1,513,735 $1,528,828 System Energy $630,750 $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Texas [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2019 Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.17% $— $— Entergy Arkansas September 2024 $150 million (c) 3.17% $— $— Entergy Louisiana September 2024 $350 million (c) 3.17% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.54% $— $— Entergy Mississippi May 2020 $35 million (d) 3.54% $— $— Entergy Mississippi May 2020 $10 million (d) 3.54% $— $— Entergy New Orleans November 2021 $25 million (c) 3.32% $— $0.8 million Entergy Texas September 2024 $150 million (c) 3.54% $— $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 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 September 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $11.7 million Entergy Mississippi $65 million 0.70% $8.1 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $26.2 million (a) As of September 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (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 $— Entergy New Orleans $150 $46 Entergy Texas $200 $— 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 September 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,458,026 $18,628,268 Entergy Arkansas $3,538,384 $3,621,073 Entergy Louisiana $7,344,160 $8,038,675 Entergy Mississippi $1,469,454 $1,586,199 Entergy New Orleans $478,619 $522,688 Entergy Texas $1,938,303 $2,128,842 System Energy $570,001 $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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, 2018 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,168,312 $15,880,239 Entergy Arkansas $3,225,759 $3,002,627 Entergy Louisiana $6,805,768 $6,834,134 Entergy Mississippi $1,325,750 $1,276,452 Entergy New Orleans $483,704 $491,569 Entergy Texas $1,513,735 $1,528,828 System Energy $630,750 $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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 are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (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 $— Entergy New Orleans $150 $46 Entergy Texas $200 $— 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 September 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.41% $30.3 Entergy Louisiana River Bend VIE September 2021 $105 3.37% $84.3 Entergy Louisiana Waterford VIE September 2021 $105 3.41% $65.5 System Energy VIE September 2021 $120 3.42% $53.6 (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 are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.42% Series J due April 2021 $100 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 September 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,458,026 $18,628,268 Entergy Arkansas $3,538,384 $3,621,073 Entergy Louisiana $7,344,160 $8,038,675 Entergy Mississippi $1,469,454 $1,586,199 Entergy New Orleans $478,619 $522,688 Entergy Texas $1,938,303 $2,128,842 System Energy $570,001 $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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, 2018 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,168,312 $15,880,239 Entergy Arkansas $3,225,759 $3,002,627 Entergy Louisiana $6,805,768 $6,834,134 Entergy Mississippi $1,325,750 $1,276,452 Entergy New Orleans $483,704 $491,569 Entergy Texas $1,513,735 $1,528,828 System Energy $630,750 $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are 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]	9 Months Ended
	Sep. 30, 2019
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 September 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $0.9 $1.1 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 $0.1 The following table includes financial information for outstanding stock options for the nine months ended September 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $2.9 $3.3 Tax benefit recognized in Entergy’s net income $0.7 $0.8 Compensation cost capitalized as part of fixed assets and materials and supplies $1.0 $0.5
Financial Information For Restricted Stock	The following table includes financial information for other outstanding equity awards for the three months ended September 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $8.4 $8.5 Tax benefit recognized in Entergy’s net income $2.1 $2.2 Compensation cost capitalized as part of fixed assets and materials and supplies $3.0 $2.5 The following table includes financial information for other outstanding equity awards for the nine months ended September 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $25.6 $26.0 Tax benefit recognized in Entergy’s net income $6.5 $6.6 Compensation cost capitalized as part of fixed assets and materials and supplies $8.8 $7.3

Retirement And Other Postreti_2

Retirement And Other Postretirement Benefits (Tables)	9 Months Ended
	Sep. 30, 2019
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 third quarters of 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,375 ($50 ) $5,325 Amortization of net gain (loss) (20,686 ) 308 (541 ) (20,919 ) Settlement loss (16,257 ) — (373 ) (16,630 ) ($36,943 ) $5,683 ($964 ) ($32,224 ) Entergy Louisiana Amortization of prior service credit $— $1,837 $— $1,837 Amortization of net gain (loss) (699 ) 174 (1 ) (526 ) ($699 ) $2,011 ($1 ) $1,311 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($297 ) $16,786 ($211 ) $16,278 Amortization of net loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of net loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032
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 third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,553 $38,752 Interest cost on projected benefit obligation 73,261 66,854 Expected return on assets (103,751 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 60,395 68,526 Settlement charges 16,291 — Net pension costs $79,749 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $100,766 $116,256 Interest cost on projected benefit obligation 221,114 200,562 Expected return on assets (311,494 ) (331,605 ) Amortization of prior service cost — 297 Amortization of net loss 177,233 205,578 Settlement charges 17,591 — Net pension costs $205,210 $191,088
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $4,675 $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975 12,681 Expected return on assets (9,562 ) (10,373 ) Amortization of prior service credit (8,844 ) (9,251 ) Amortization of net loss 358 3,432 Net other postretirement benefit cost (income) ($1,398 ) $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $14,025 $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925 38,043 Expected return on assets (28,686 ) (31,119 ) Amortization of prior service credit (26,532 ) (27,753 ) Amortization of net loss 1,074 10,296 Net other postretirement benefit cost (income) ($4,194 ) $9,813
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 third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,260 $7,284 $1,629 $568 $1,350 $1,549 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,873 3,613 3,364 Expected return on assets (20,177 ) (22,651 ) (5,969 ) (2,696 ) (5,862 ) (4,678 ) Amortization of net loss 11,840 11,643 3,104 1,529 2,334 2,850 Net pension cost $11,098 $12,158 $2,832 $1,274 $1,435 $3,085 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projected benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of net loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,782 $21,852 $4,887 $1,706 $4,050 $4,649 Interest cost on projected benefit obligation 42,525 47,646 12,204 5,621 10,837 10,091 Expected return on assets (60,529 ) (67,955 ) (17,905 ) (8,089 ) (17,586 ) (14,032 ) Amortization of net loss 35,522 34,929 9,313 4,588 7,002 8,550 Net pension cost $33,300 $36,472 $8,499 $3,826 $4,303 $9,258 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projected benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of net loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2019 pension contributions $27,112 $26,451 $7,701 $1,800 $1,645 $8,285 Pension contributions made through September 2019 $18,222 $18,272 $5,186 $1,237 $1,192 $5,631 Remaining estimated pension contributions to be made in 2019 $8,890 $8,179 $2,515 $563 $453 $2,654
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 third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $591 $1,160 $262 $92 $236 $243 Interest cost on APBO 1,807 2,666 670 395 854 476 Expected return on assets (3,991 ) — (1,199 ) (1,237 ) (2,276 ) (697 ) Amortization of prior service credit (1,238 ) (1,837 ) (439 ) (171 ) (561 ) (363 ) Amortization of net (gain) loss 144 (174 ) 181 58 121 89 Net other postretirement benefit cost (income) ($2,687 ) $1,815 ($525 ) ($863 ) ($1,626 ) ($252 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of net loss 289 388 377 34 206 233 Net other postretirement benefit cost (income) ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,773 $3,480 $786 $276 $708 $729 Interest cost on APBO 5,421 7,998 2,010 1,185 2,562 1,428 Expected return on assets (11,973 ) — (3,597 ) (3,711 ) (6,828 ) (2,091 ) Amortization of prior service credit (3,714 ) (5,511 ) (1,317 ) (513 ) (1,683 ) (1,089 ) Amortization of net (gain) loss 432 (522 ) 543 174 363 267 Net other postretirement benefit cost (income) ($8,061 ) $5,445 ($1,575 ) ($2,589 ) ($4,878 ) ($756 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of net loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost (income) ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 )
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 third quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $67 $38 $69 $5 $119 2018 $114 $42 $73 $20 $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $211 $122 $257 $16 $365 2018 $369 $138 $230 $62 $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan.
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 third quarters of 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,375 ($50 ) $5,325 Amortization of net gain (loss) (20,686 ) 308 (541 ) (20,919 ) Settlement loss (16,257 ) — (373 ) (16,630 ) ($36,943 ) $5,683 ($964 ) ($32,224 ) Entergy Louisiana Amortization of prior service credit $— $1,837 $— $1,837 Amortization of net gain (loss) (699 ) 174 (1 ) (526 ) ($699 ) $2,011 ($1 ) $1,311 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($297 ) $16,786 ($211 ) $16,278 Amortization of net loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of net loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032
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 third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,260 $7,284 $1,629 $568 $1,350 $1,549 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,873 3,613 3,364 Expected return on assets (20,177 ) (22,651 ) (5,969 ) (2,696 ) (5,862 ) (4,678 ) Amortization of net loss 11,840 11,643 3,104 1,529 2,334 2,850 Net pension cost $11,098 $12,158 $2,832 $1,274 $1,435 $3,085 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projected benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of net loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,782 $21,852 $4,887 $1,706 $4,050 $4,649 Interest cost on projected benefit obligation 42,525 47,646 12,204 5,621 10,837 10,091 Expected return on assets (60,529 ) (67,955 ) (17,905 ) (8,089 ) (17,586 ) (14,032 ) Amortization of net loss 35,522 34,929 9,313 4,588 7,002 8,550 Net pension cost $33,300 $36,472 $8,499 $3,826 $4,303 $9,258 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projected benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of net loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2019 pension contributions $27,112 $26,451 $7,701 $1,800 $1,645 $8,285 Pension contributions made through September 2019 $18,222 $18,272 $5,186 $1,237 $1,192 $5,631 Remaining estimated pension contributions to be made in 2019 $8,890 $8,179 $2,515 $563 $453 $2,654
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 third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $591 $1,160 $262 $92 $236 $243 Interest cost on APBO 1,807 2,666 670 395 854 476 Expected return on assets (3,991 ) — (1,199 ) (1,237 ) (2,276 ) (697 ) Amortization of prior service credit (1,238 ) (1,837 ) (439 ) (171 ) (561 ) (363 ) Amortization of net (gain) loss 144 (174 ) 181 58 121 89 Net other postretirement benefit cost (income) ($2,687 ) $1,815 ($525 ) ($863 ) ($1,626 ) ($252 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of net loss 289 388 377 34 206 233 Net other postretirement benefit cost (income) ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,773 $3,480 $786 $276 $708 $729 Interest cost on APBO 5,421 7,998 2,010 1,185 2,562 1,428 Expected return on assets (11,973 ) — (3,597 ) (3,711 ) (6,828 ) (2,091 ) Amortization of prior service credit (3,714 ) (5,511 ) (1,317 ) (513 ) (1,683 ) (1,089 ) Amortization of net (gain) loss 432 (522 ) 543 174 363 267 Net other postretirement benefit cost (income) ($8,061 ) $5,445 ($1,575 ) ($2,589 ) ($4,878 ) ($756 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of net loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost (income) ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 )
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 third quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $67 $38 $69 $5 $119 2018 $114 $42 $73 $20 $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $211 $122 $257 $16 $365 2018 $369 $138 $230 $62 $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan.
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 third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,260 $7,284 $1,629 $568 $1,350 $1,549 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,873 3,613 3,364 Expected return on assets (20,177 ) (22,651 ) (5,969 ) (2,696 ) (5,862 ) (4,678 ) Amortization of net loss 11,840 11,643 3,104 1,529 2,334 2,850 Net pension cost $11,098 $12,158 $2,832 $1,274 $1,435 $3,085 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projected benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of net loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,782 $21,852 $4,887 $1,706 $4,050 $4,649 Interest cost on projected benefit obligation 42,525 47,646 12,204 5,621 10,837 10,091 Expected return on assets (60,529 ) (67,955 ) (17,905 ) (8,089 ) (17,586 ) (14,032 ) Amortization of net loss 35,522 34,929 9,313 4,588 7,002 8,550 Net pension cost $33,300 $36,472 $8,499 $3,826 $4,303 $9,258 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projected benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of net loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2019 pension contributions $27,112 $26,451 $7,701 $1,800 $1,645 $8,285 Pension contributions made through September 2019 $18,222 $18,272 $5,186 $1,237 $1,192 $5,631 Remaining estimated pension contributions to be made in 2019 $8,890 $8,179 $2,515 $563 $453 $2,654
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 third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $591 $1,160 $262 $92 $236 $243 Interest cost on APBO 1,807 2,666 670 395 854 476 Expected return on assets (3,991 ) — (1,199 ) (1,237 ) (2,276 ) (697 ) Amortization of prior service credit (1,238 ) (1,837 ) (439 ) (171 ) (561 ) (363 ) Amortization of net (gain) loss 144 (174 ) 181 58 121 89 Net other postretirement benefit cost (income) ($2,687 ) $1,815 ($525 ) ($863 ) ($1,626 ) ($252 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of net loss 289 388 377 34 206 233 Net other postretirement benefit cost (income) ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,773 $3,480 $786 $276 $708 $729 Interest cost on APBO 5,421 7,998 2,010 1,185 2,562 1,428 Expected return on assets (11,973 ) — (3,597 ) (3,711 ) (6,828 ) (2,091 ) Amortization of prior service credit (3,714 ) (5,511 ) (1,317 ) (513 ) (1,683 ) (1,089 ) Amortization of net (gain) loss 432 (522 ) 543 174 363 267 Net other postretirement benefit cost (income) ($8,061 ) $5,445 ($1,575 ) ($2,589 ) ($4,878 ) ($756 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of net loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost (income) ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 )
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 third quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $67 $38 $69 $5 $119 2018 $114 $42 $73 $20 $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $211 $122 $257 $16 $365 2018 $369 $138 $230 $62 $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan.
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 third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,260 $7,284 $1,629 $568 $1,350 $1,549 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,873 3,613 3,364 Expected return on assets (20,177 ) (22,651 ) (5,969 ) (2,696 ) (5,862 ) (4,678 ) Amortization of net loss 11,840 11,643 3,104 1,529 2,334 2,850 Net pension cost $11,098 $12,158 $2,832 $1,274 $1,435 $3,085 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projected benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of net loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,782 $21,852 $4,887 $1,706 $4,050 $4,649 Interest cost on projected benefit obligation 42,525 47,646 12,204 5,621 10,837 10,091 Expected return on assets (60,529 ) (67,955 ) (17,905 ) (8,089 ) (17,586 ) (14,032 ) Amortization of net loss 35,522 34,929 9,313 4,588 7,002 8,550 Net pension cost $33,300 $36,472 $8,499 $3,826 $4,303 $9,258 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projected benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of net loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2019 pension contributions $27,112 $26,451 $7,701 $1,800 $1,645 $8,285 Pension contributions made through September 2019 $18,222 $18,272 $5,186 $1,237 $1,192 $5,631 Remaining estimated pension contributions to be made in 2019 $8,890 $8,179 $2,515 $563 $453 $2,654
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 third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $591 $1,160 $262 $92 $236 $243 Interest cost on APBO 1,807 2,666 670 395 854 476 Expected return on assets (3,991 ) — (1,199 ) (1,237 ) (2,276 ) (697 ) Amortization of prior service credit (1,238 ) (1,837 ) (439 ) (171 ) (561 ) (363 ) Amortization of net (gain) loss 144 (174 ) 181 58 121 89 Net other postretirement benefit cost (income) ($2,687 ) $1,815 ($525 ) ($863 ) ($1,626 ) ($252 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of net loss 289 388 377 34 206 233 Net other postretirement benefit cost (income) ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,773 $3,480 $786 $276 $708 $729 Interest cost on APBO 5,421 7,998 2,010 1,185 2,562 1,428 Expected return on assets (11,973 ) — (3,597 ) (3,711 ) (6,828 ) (2,091 ) Amortization of prior service credit (3,714 ) (5,511 ) (1,317 ) (513 ) (1,683 ) (1,089 ) Amortization of net (gain) loss 432 (522 ) 543 174 363 267 Net other postretirement benefit cost (income) ($8,061 ) $5,445 ($1,575 ) ($2,589 ) ($4,878 ) ($756 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of net loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost (income) ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 )
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 third quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $67 $38 $69 $5 $119 2018 $114 $42 $73 $20 $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $211 $122 $257 $16 $365 2018 $369 $138 $230 $62 $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan.
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 third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,260 $7,284 $1,629 $568 $1,350 $1,549 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,873 3,613 3,364 Expected return on assets (20,177 ) (22,651 ) (5,969 ) (2,696 ) (5,862 ) (4,678 ) Amortization of net loss 11,840 11,643 3,104 1,529 2,334 2,850 Net pension cost $11,098 $12,158 $2,832 $1,274 $1,435 $3,085 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projected benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of net loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,782 $21,852 $4,887 $1,706 $4,050 $4,649 Interest cost on projected benefit obligation 42,525 47,646 12,204 5,621 10,837 10,091 Expected return on assets (60,529 ) (67,955 ) (17,905 ) (8,089 ) (17,586 ) (14,032 ) Amortization of net loss 35,522 34,929 9,313 4,588 7,002 8,550 Net pension cost $33,300 $36,472 $8,499 $3,826 $4,303 $9,258 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projected benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of net loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2019 pension contributions $27,112 $26,451 $7,701 $1,800 $1,645 $8,285 Pension contributions made through September 2019 $18,222 $18,272 $5,186 $1,237 $1,192 $5,631 Remaining estimated pension contributions to be made in 2019 $8,890 $8,179 $2,515 $563 $453 $2,654
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 third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $591 $1,160 $262 $92 $236 $243 Interest cost on APBO 1,807 2,666 670 395 854 476 Expected return on assets (3,991 ) — (1,199 ) (1,237 ) (2,276 ) (697 ) Amortization of prior service credit (1,238 ) (1,837 ) (439 ) (171 ) (561 ) (363 ) Amortization of net (gain) loss 144 (174 ) 181 58 121 89 Net other postretirement benefit cost (income) ($2,687 ) $1,815 ($525 ) ($863 ) ($1,626 ) ($252 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of net loss 289 388 377 34 206 233 Net other postretirement benefit cost (income) ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,773 $3,480 $786 $276 $708 $729 Interest cost on APBO 5,421 7,998 2,010 1,185 2,562 1,428 Expected return on assets (11,973 ) — (3,597 ) (3,711 ) (6,828 ) (2,091 ) Amortization of prior service credit (3,714 ) (5,511 ) (1,317 ) (513 ) (1,683 ) (1,089 ) Amortization of net (gain) loss 432 (522 ) 543 174 363 267 Net other postretirement benefit cost (income) ($8,061 ) $5,445 ($1,575 ) ($2,589 ) ($4,878 ) ($756 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of net loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost (income) ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 )
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 third quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $67 $38 $69 $5 $119 2018 $114 $42 $73 $20 $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $211 $122 $257 $16 $365 2018 $369 $138 $230 $62 $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan.
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 third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,260 $7,284 $1,629 $568 $1,350 $1,549 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,873 3,613 3,364 Expected return on assets (20,177 ) (22,651 ) (5,969 ) (2,696 ) (5,862 ) (4,678 ) Amortization of net loss 11,840 11,643 3,104 1,529 2,334 2,850 Net pension cost $11,098 $12,158 $2,832 $1,274 $1,435 $3,085 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projected benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of net loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,782 $21,852 $4,887 $1,706 $4,050 $4,649 Interest cost on projected benefit obligation 42,525 47,646 12,204 5,621 10,837 10,091 Expected return on assets (60,529 ) (67,955 ) (17,905 ) (8,089 ) (17,586 ) (14,032 ) Amortization of net loss 35,522 34,929 9,313 4,588 7,002 8,550 Net pension cost $33,300 $36,472 $8,499 $3,826 $4,303 $9,258 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projected benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of net loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2019 pension contributions $27,112 $26,451 $7,701 $1,800 $1,645 $8,285 Pension contributions made through September 2019 $18,222 $18,272 $5,186 $1,237 $1,192 $5,631 Remaining estimated pension contributions to be made in 2019 $8,890 $8,179 $2,515 $563 $453 $2,654
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 third quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $591 $1,160 $262 $92 $236 $243 Interest cost on APBO 1,807 2,666 670 395 854 476 Expected return on assets (3,991 ) — (1,199 ) (1,237 ) (2,276 ) (697 ) Amortization of prior service credit (1,238 ) (1,837 ) (439 ) (171 ) (561 ) (363 ) Amortization of net (gain) loss 144 (174 ) 181 58 121 89 Net other postretirement benefit cost (income) ($2,687 ) $1,815 ($525 ) ($863 ) ($1,626 ) ($252 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of net loss 289 388 377 34 206 233 Net other postretirement benefit cost (income) ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,773 $3,480 $786 $276 $708 $729 Interest cost on APBO 5,421 7,998 2,010 1,185 2,562 1,428 Expected return on assets (11,973 ) — (3,597 ) (3,711 ) (6,828 ) (2,091 ) Amortization of prior service credit (3,714 ) (5,511 ) (1,317 ) (513 ) (1,683 ) (1,089 ) Amortization of net (gain) loss 432 (522 ) 543 174 363 267 Net other postretirement benefit cost (income) ($8,061 ) $5,445 ($1,575 ) ($2,589 ) ($4,878 ) ($756 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of net loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost (income) ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 )

Business Segment Information (T

Business Segment Information (Tables) - Entergy Corporation [Member]	9 Months Ended
	Sep. 30, 2019
Segment Financial Information	Entergy’s segment financial information for the third quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,840,222 $300,363 $9 ($19 ) $3,140,575 Income taxes $71,698 ($30,855 ) ($11,642 ) $— $29,201 Consolidated net income (loss) $581,964 ($140,501 ) ($40,105 ) ($31,899 ) $369,459 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $7,392,641 $1,023,757 $11 ($42 ) $8,416,367 Income taxes $81,283 $25,763 ($33,616 ) $— $73,430 Consolidated net income (loss) $1,150,863 ($68,804 ) ($117,725 ) ($95,695 ) $868,639 Total assets as of September 30, 2019 $48,348,371 $4,122,007 $501,983 ($2,466,093 ) $50,506,268 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of December 31, 2018 $44,777,167 $5,459,275 $733,366 ($2,694,742 ) $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.
Restructuring and Related Costs [Table Text Block]	Total restructuring charges for the third quarters of 2019 and 2018 were comprised of the following: 2019 2018 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $181 $14 $195 $143 $14 $157 Restructuring costs accrued 14 — 14 43 — 43 Cash paid out 86 — 86 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following: 2019 2018 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, $179 $14 $193 $83 $14 $97 Restructuring costs accrued 70 — 70 103 — 103 Cash paid out 140 — 140 — — — Balance as of September 30, $109 $14 $123 $186 $14 $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 of impairment and other related charges associated with these strategic decisions and transactions.

Risk Management And Fair Valu_2

Risk Management And Fair Values (Tables)	9 Months Ended
	Sep. 30, 2019
Fair Values Of Derivative Instruments	The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $35 ($5) $30 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $14 ($2) $12 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $5 ($5) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($3) $6 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $17 ($1) $16 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $4 $— $4 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 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 Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $32 ($32) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $7 ($7) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $54 ($33) $21 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $20 ($7) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $4 ($2) $2 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Entergy Wholesale Commodities Natural gas swaps and options Other deferred debits and other assets (non-current portion) $2 $— $2 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $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 $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018.
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 September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2019 Electricity swaps and options ($7) Competitive businesses operating revenues $19 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2019 Electricity swaps and options $145 Competitive businesses operating revenues $76 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, 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 September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights $— Purchased power expense (b) $25 Electricity swaps and options $— (c) Competitive business operating revenues $1 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 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 nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2019 Natural gas swaps and options $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options $— (c) Competitive business operating revenues $4 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— (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) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items.
Assets and liabilities at fair value on a recurring basis	The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018 . 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. 2019 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $885 $— $— $885 Decommissioning trust funds (a): Equity securities 836 — — 836 Debt securities 1,214 1,754 — 2,968 Common trusts (b) 2,325 Power contracts — — 48 48 Securitization recovery trust account 55 — — 55 Escrow accounts 410 — — 410 Gas hedge contracts — 1 — 1 Financial transmission rights — — 16 16 $3,400 $1,755 $64 $7,544 Liabilities: Gas hedge contracts $4 $1 $— $5 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $424 $— $— $424 Decommissioning trust funds (a): Equity securities 1,686 — — 1,686 Debt securities 1,259 1,625 — 2,884 Common trusts (b) 2,350 Power contracts — — 3 3 Securitization recovery trust account 51 — — 51 Escrow accounts 403 — — 403 Gas hedge contracts — 2 — 2 Financial transmission rights — — 15 15 $3,823 $1,627 $18 $7,818 Liabilities: Power contracts $— $— $34 $34 Gas hedge contracts 1 — — 1 $1 $— $34 $35 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.
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 September 30, 2019 and 2018 : 2019 2018 Power Contracts Financial transmission rights Power Contracts Financial transmission rights (In Millions) Balance as of July 1, $72 $29 ($25 ) $41 Total gains (losses) for the period (a) Included in earnings 1 — (4 ) — Included in other comprehensive income (7 ) — (51 ) — Included as a regulatory liability/asset — 12 — 19 Settlements (18 ) (25 ) 13 (31 ) Balance as of September 30, $48 $16 ($67 ) $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($1.2) million for the three months ended September 30, 2019 and $1.7 million for the three months ended September 30, 2018. 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 nine months ended September 30, 2019 and 2018 : 2019 2018 Power Contracts Financial transmission rights Power Contracts Financial transmission rights (In Millions) Balance as of January 1, ($31 ) $15 ($65 ) $21 Total gains (losses) for the period (a) Included in earnings 4 — (5 ) (1 ) Included in other comprehensive income 145 — (40 ) — Included as a regulatory liability/asset — 44 — 67 Issuances of financial transmission rights — 35 — 46 Settlements (70 ) (78 ) 43 (104 ) Balance as of September 30, $48 $16 ($67 ) $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($4.7) million for the nine months ended September 30, 2019 and $1.1 million for the nine months ended September 30, 2018.
Fair Value Inputs Liabilities Quantitative Information	The following table sets forth a description of the types of transactions classified as Level 3 in the fair value hierarchy and significant unobservable inputs to each which cause that classification as of September 30, 2019 : Transaction Type Fair Value Significant Unobservable Inputs Range from Average % Effect on Fair Value (In Millions) (In Millions) Power contracts - electricity swaps $48 Unit contingent discount +/- 4% - 4.75% $4 - $5
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 September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.1 $— $0.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1.0 $— $1.0 Entergy Louisiana Financial transmission rights Prepayments and other $4.0 ($0.1) $3.9 Entergy Arkansas Financial transmission rights Prepayments and other $9.1 $— $9.1 Entergy Louisiana Financial transmission rights Prepayments and other $1.5 $— $1.5 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($0.4) $1.3 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $2.2 $— $2.2 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.4 $— $1.4 Entergy Louisiana Natural gas swaps Other current liabilities $1.1 $— $1.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.1 $— $0.1 Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $1.6 $— $1.6 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.4 ($0.1) $8.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.3 $— $1.3 Entergy New Orleans Liabilities: Financial transmission rights Other current liabilities $0.9 ($1.4) ($0.5) Entergy Texas Natural gas swaps and options Other current liabilities $1.1 $— $1.1 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 $— $0.1 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 September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million
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 September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.3) (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 $3.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $14.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $1.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense ($0.3) (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.5 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($3.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.5) (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 $15.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $40.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $13.6 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (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 2019 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $76.7 $— $— $76.7 Decommissioning trust funds (a): Equity securities 6.2 — — 6.2 Debt securities 101.4 306.3 — 407.7 Common trusts (b) 631.9 Securitization recovery trust account 7.9 — — 7.9 Financial transmission rights — — 3.9 3.9 $192.2 $306.3 $3.9 $1,134.3 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Decommissioning trust funds (a): Equity securities $4.0 $— $— $4.0 Debt securities 94.8 286.5 — 381.3 Common trusts (b) 526.7 Securitization recovery trust account 4.7 — — 4.7 Financial transmission rights — — 3.4 3.4 $103.5 $286.5 $3.4 $920.1
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 September 30, 2019 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, $8.2 $15.6 $2.8 $2.0 $0.6 Gains (losses) included as a regulatory liability/asset (0.8 ) 7.9 0.6 (1.6 ) 6.2 Settlements (3.5 ) (14.4 ) (1.9 ) 0.3 (5.5 ) Balance as of September 30, $3.9 $9.1 $1.5 $0.7 $1.3 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 September 30, 2018 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, $10.5 $18.2 $4.4 $3.0 $4.7 Gains (losses) included as a regulatory liability/asset 10.9 7.6 4.7 1.1 (5.0 ) Settlements (10.1 ) (13.8 ) (5.4 ) (2.0 ) 0.4 Balance as of September 30, $11.3 $12.0 $3.7 $2.1 $0.1 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 nine months ended September 30, 2019 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $3.4 $8.3 $2.2 $1.3 ($0.5 ) Issuances of financial transmission rights 9.6 18.7 3.9 2.7 0.1 Gains (losses) included as a regulatory liability/asset 6.3 23.0 0.6 (1.1 ) 15.3 Settlements (15.4 ) (40.9 ) (5.2 ) (2.2 ) (13.6 ) Balance as of September 30, $3.9 $9.1 $1.5 $0.7 $1.3 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 nine months ended September 30, 2018 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $3.0 $10.2 $2.1 $2.2 $3.4 Issuances of financial transmission rights 11.8 20.0 4.5 3.7 6.1 Gains (losses) included as a regulatory liability/asset 16.6 39.0 20.1 6.7 (15.0 ) Settlements (20.1 ) (57.2 ) (23.0 ) (10.5 ) 5.6 Balance as of September 30, $11.3 $12.0 $3.7 $2.1 $0.1
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 September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.1 $— $0.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1.0 $— $1.0 Entergy Louisiana Financial transmission rights Prepayments and other $4.0 ($0.1) $3.9 Entergy Arkansas Financial transmission rights Prepayments and other $9.1 $— $9.1 Entergy Louisiana Financial transmission rights Prepayments and other $1.5 $— $1.5 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($0.4) $1.3 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $2.2 $— $2.2 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.4 $— $1.4 Entergy Louisiana Natural gas swaps Other current liabilities $1.1 $— $1.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.1 $— $0.1 Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $1.6 $— $1.6 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.4 ($0.1) $8.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.3 $— $1.3 Entergy New Orleans Liabilities: Financial transmission rights Other current liabilities $0.9 ($1.4) ($0.5) Entergy Texas Natural gas swaps and options Other current liabilities $1.1 $— $1.1 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 $— $0.1 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 September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million
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 September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.3) (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 $3.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $14.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $1.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense ($0.3) (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.5 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($3.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.5) (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 $15.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $40.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $13.6 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (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 2019 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $127.8 $— $— $127.8 Decommissioning trust funds (a): Equity securities 5.3 — — 5.3 Debt securities 183.7 409.7 — 593.4 Common trusts (b) 886.9 Escrow accounts 294.5 — — 294.5 Securitization recovery trust account 10.1 — — 10.1 Gas hedge contracts 0.1 1.0 — 1.1 Financial transmission rights — — 9.1 9.1 $621.5 $410.7 $9.1 $1,928.2 Liabilities: Gas hedge contracts $2.2 $1.4 $— $3.6 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $43.1 $— $— $43.1 Decommissioning trust funds (a): Equity securities 13.3 — — 13.3 Debt securities 162.0 370.9 — 532.9 Common trusts (b) 738.8 Escrow accounts 289.5 — — 289.5 Securitization recovery trust account 3.6 — — 3.6 Gas hedge contracts — 1.9 — 1.9 Financial transmission rights — — 8.3 8.3 $511.5 $372.8 $8.3 $1,631.4 Liabilities: Gas hedge contracts $0.7 $0.4 $— $1.1
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 September 30, 2019 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, $8.2 $15.6 $2.8 $2.0 $0.6 Gains (losses) included as a regulatory liability/asset (0.8 ) 7.9 0.6 (1.6 ) 6.2 Settlements (3.5 ) (14.4 ) (1.9 ) 0.3 (5.5 ) Balance as of September 30, $3.9 $9.1 $1.5 $0.7 $1.3 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 September 30, 2018 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, $10.5 $18.2 $4.4 $3.0 $4.7 Gains (losses) included as a regulatory liability/asset 10.9 7.6 4.7 1.1 (5.0 ) Settlements (10.1 ) (13.8 ) (5.4 ) (2.0 ) 0.4 Balance as of September 30, $11.3 $12.0 $3.7 $2.1 $0.1 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 nine months ended September 30, 2019 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $3.4 $8.3 $2.2 $1.3 ($0.5 ) Issuances of financial transmission rights 9.6 18.7 3.9 2.7 0.1 Gains (losses) included as a regulatory liability/asset 6.3 23.0 0.6 (1.1 ) 15.3 Settlements (15.4 ) (40.9 ) (5.2 ) (2.2 ) (13.6 ) Balance as of September 30, $3.9 $9.1 $1.5 $0.7 $1.3 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 nine months ended September 30, 2018 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $3.0 $10.2 $2.1 $2.2 $3.4 Issuances of financial transmission rights 11.8 20.0 4.5 3.7 6.1 Gains (losses) included as a regulatory liability/asset 16.6 39.0 20.1 6.7 (15.0 ) Settlements (20.1 ) (57.2 ) (23.0 ) (10.5 ) 5.6 Balance as of September 30, $11.3 $12.0 $3.7 $2.1 $0.1
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 September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.1 $— $0.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1.0 $— $1.0 Entergy Louisiana Financial transmission rights Prepayments and other $4.0 ($0.1) $3.9 Entergy Arkansas Financial transmission rights Prepayments and other $9.1 $— $9.1 Entergy Louisiana Financial transmission rights Prepayments and other $1.5 $— $1.5 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($0.4) $1.3 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $2.2 $— $2.2 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.4 $— $1.4 Entergy Louisiana Natural gas swaps Other current liabilities $1.1 $— $1.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.1 $— $0.1 Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $1.6 $— $1.6 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.4 ($0.1) $8.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.3 $— $1.3 Entergy New Orleans Liabilities: Financial transmission rights Other current liabilities $0.9 ($1.4) ($0.5) Entergy Texas Natural gas swaps and options Other current liabilities $1.1 $— $1.1 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 $— $0.1 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 September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million
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 September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.3) (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 $3.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $14.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $1.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense ($0.3) (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.5 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($3.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.5) (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 $15.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $40.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $13.6 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (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 2019 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $98.9 $— $— $98.9 Escrow accounts 33.0 — — 33.0 Financial transmission rights — — 1.5 1.5 $131.9 $— $1.5 $133.4 Liabilities: Gas hedge contracts $1.1 $— $— $1.1 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $36.9 $— $— $36.9 Escrow accounts 32.4 — — 32.4 Financial transmission rights — — 2.2 2.2 $69.3 $— $2.2 $71.5
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 September 30, 2019 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, $8.2 $15.6 $2.8 $2.0 $0.6 Gains (losses) included as a regulatory liability/asset (0.8 ) 7.9 0.6 (1.6 ) 6.2 Settlements (3.5 ) (14.4 ) (1.9 ) 0.3 (5.5 ) Balance as of September 30, $3.9 $9.1 $1.5 $0.7 $1.3 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 September 30, 2018 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, $10.5 $18.2 $4.4 $3.0 $4.7 Gains (losses) included as a regulatory liability/asset 10.9 7.6 4.7 1.1 (5.0 ) Settlements (10.1 ) (13.8 ) (5.4 ) (2.0 ) 0.4 Balance as of September 30, $11.3 $12.0 $3.7 $2.1 $0.1 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 nine months ended September 30, 2019 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $3.4 $8.3 $2.2 $1.3 ($0.5 ) Issuances of financial transmission rights 9.6 18.7 3.9 2.7 0.1 Gains (losses) included as a regulatory liability/asset 6.3 23.0 0.6 (1.1 ) 15.3 Settlements (15.4 ) (40.9 ) (5.2 ) (2.2 ) (13.6 ) Balance as of September 30, $3.9 $9.1 $1.5 $0.7 $1.3 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 nine months ended September 30, 2018 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $3.0 $10.2 $2.1 $2.2 $3.4 Issuances of financial transmission rights 11.8 20.0 4.5 3.7 6.1 Gains (losses) included as a regulatory liability/asset 16.6 39.0 20.1 6.7 (15.0 ) Settlements (20.1 ) (57.2 ) (23.0 ) (10.5 ) 5.6 Balance as of September 30, $11.3 $12.0 $3.7 $2.1 $0.1
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 September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.1 $— $0.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1.0 $— $1.0 Entergy Louisiana Financial transmission rights Prepayments and other $4.0 ($0.1) $3.9 Entergy Arkansas Financial transmission rights Prepayments and other $9.1 $— $9.1 Entergy Louisiana Financial transmission rights Prepayments and other $1.5 $— $1.5 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($0.4) $1.3 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $2.2 $— $2.2 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.4 $— $1.4 Entergy Louisiana Natural gas swaps Other current liabilities $1.1 $— $1.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.1 $— $0.1 Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $1.6 $— $1.6 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.4 ($0.1) $8.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.3 $— $1.3 Entergy New Orleans Liabilities: Financial transmission rights Other current liabilities $0.9 ($1.4) ($0.5) Entergy Texas Natural gas swaps and options Other current liabilities $1.1 $— $1.1 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 $— $0.1 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 September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million
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 September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.3) (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 $3.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $14.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $1.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense ($0.3) (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.5 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($3.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.5) (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 $15.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $40.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $13.6 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (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 2019 Level 1 Level 2 Level 3 Total (In Millions) Assets: Securitization recovery trust account $5.3 $— $— $5.3 Escrow accounts 82.2 — — 82.2 Financial transmission rights — — 0.7 0.7 $87.5 $— $0.7 $88.2 Liabilities: Gas hedge contracts $0.1 $— $— $0.1 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $19.7 $— $— $19.7 Securitization recovery trust account 2.2 — — 2.2 Escrow accounts 80.9 — — 80.9 Financial transmission rights — — 1.3 1.3 $102.8 $— $1.3 $104.1 Liabilities: Gas hedge contracts $0.1 $— $— $0.1
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 September 30, 2019 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, $8.2 $15.6 $2.8 $2.0 $0.6 Gains (losses) included as a regulatory liability/asset (0.8 ) 7.9 0.6 (1.6 ) 6.2 Settlements (3.5 ) (14.4 ) (1.9 ) 0.3 (5.5 ) Balance as of September 30, $3.9 $9.1 $1.5 $0.7 $1.3 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 September 30, 2018 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, $10.5 $18.2 $4.4 $3.0 $4.7 Gains (losses) included as a regulatory liability/asset 10.9 7.6 4.7 1.1 (5.0 ) Settlements (10.1 ) (13.8 ) (5.4 ) (2.0 ) 0.4 Balance as of September 30, $11.3 $12.0 $3.7 $2.1 $0.1 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 nine months ended September 30, 2019 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $3.4 $8.3 $2.2 $1.3 ($0.5 ) Issuances of financial transmission rights 9.6 18.7 3.9 2.7 0.1 Gains (losses) included as a regulatory liability/asset 6.3 23.0 0.6 (1.1 ) 15.3 Settlements (15.4 ) (40.9 ) (5.2 ) (2.2 ) (13.6 ) Balance as of September 30, $3.9 $9.1 $1.5 $0.7 $1.3 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 nine months ended September 30, 2018 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $3.0 $10.2 $2.1 $2.2 $3.4 Issuances of financial transmission rights 11.8 20.0 4.5 3.7 6.1 Gains (losses) included as a regulatory liability/asset 16.6 39.0 20.1 6.7 (15.0 ) Settlements (20.1 ) (57.2 ) (23.0 ) (10.5 ) 5.6 Balance as of September 30, $11.3 $12.0 $3.7 $2.1 $0.1
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 September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.1 $— $0.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1.0 $— $1.0 Entergy Louisiana Financial transmission rights Prepayments and other $4.0 ($0.1) $3.9 Entergy Arkansas Financial transmission rights Prepayments and other $9.1 $— $9.1 Entergy Louisiana Financial transmission rights Prepayments and other $1.5 $— $1.5 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($0.4) $1.3 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $2.2 $— $2.2 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.4 $— $1.4 Entergy Louisiana Natural gas swaps Other current liabilities $1.1 $— $1.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.1 $— $0.1 Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $1.6 $— $1.6 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.4 ($0.1) $8.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.3 $— $1.3 Entergy New Orleans Liabilities: Financial transmission rights Other current liabilities $0.9 ($1.4) ($0.5) Entergy Texas Natural gas swaps and options Other current liabilities $1.1 $— $1.1 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 $— $0.1 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 September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million
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 September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.3) (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 $3.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $14.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $1.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense ($0.3) (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.5 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($3.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.5) (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 $15.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $40.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $13.6 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (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 2019 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $92.3 $— $— $92.3 Securitization recovery trust account 31.6 — — 31.6 Financial transmission rights — — 1.3 1.3 $123.9 $— $1.3 $125.2 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets : Securitization recovery trust account $40.2 $— $— $40.2 Liabilities: Financial transmission rights $— $— $0.5 $0.5
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 September 30, 2019 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, $8.2 $15.6 $2.8 $2.0 $0.6 Gains (losses) included as a regulatory liability/asset (0.8 ) 7.9 0.6 (1.6 ) 6.2 Settlements (3.5 ) (14.4 ) (1.9 ) 0.3 (5.5 ) Balance as of September 30, $3.9 $9.1 $1.5 $0.7 $1.3 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 September 30, 2018 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, $10.5 $18.2 $4.4 $3.0 $4.7 Gains (losses) included as a regulatory liability/asset 10.9 7.6 4.7 1.1 (5.0 ) Settlements (10.1 ) (13.8 ) (5.4 ) (2.0 ) 0.4 Balance as of September 30, $11.3 $12.0 $3.7 $2.1 $0.1 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 nine months ended September 30, 2019 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $3.4 $8.3 $2.2 $1.3 ($0.5 ) Issuances of financial transmission rights 9.6 18.7 3.9 2.7 0.1 Gains (losses) included as a regulatory liability/asset 6.3 23.0 0.6 (1.1 ) 15.3 Settlements (15.4 ) (40.9 ) (5.2 ) (2.2 ) (13.6 ) Balance as of September 30, $3.9 $9.1 $1.5 $0.7 $1.3 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 nine months ended September 30, 2018 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $3.0 $10.2 $2.1 $2.2 $3.4 Issuances of financial transmission rights 11.8 20.0 4.5 3.7 6.1 Gains (losses) included as a regulatory liability/asset 16.6 39.0 20.1 6.7 (15.0 ) Settlements (20.1 ) (57.2 ) (23.0 ) (10.5 ) 5.6 Balance as of September 30, $11.3 $12.0 $3.7 $2.1 $0.1
System Energy [Member]
Assets and liabilities at fair value on a recurring basis	System Energy 2019 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $164.2 $— $— $164.2 Decommissioning trust funds (a): Equity securities 5.8 — — 5.8 Debt securities 206.0 189.3 — 395.3 Common trusts (b) 601.2 $376.0 $189.3 $— $1,166.5 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $95.6 $— $— $95.6 Decommissioning trust funds (a): Equity securities 4.4 — — 4.4 Debt securities 224.5 139.7 — 364.2 Common trusts (b) 500.9 $324.5 $139.7 $— $965.1

Decommissioning Trust Funds (Ta

Decommissioning Trust Funds (Tables)	9 Months Ended
	Sep. 30, 2019
Securities Held	The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities (a) $2,462 $114 $2 2018 Debt Securities (a) $2,495 $19 $35 (a) Debt securities presented herein do not include the $506 million and $389 million of debt securities held in the wholly-owned registered investment company as of September 30, 2019 and December 31, 2018 , respectively, which are not accounted for as available-for-sale.
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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $236 $2 More than 12 months 67 — Total $303 $2 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $652 $9 More than 12 months 782 26 Total $1,434 $35
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $165 $199 1 year - 5 years 870 1,066 5 years - 10 years 636 544 10 years - 15 years 89 77 15 years - 20 years 98 78 20 years+ 604 531 Total $2,462 $2,495
Entergy Arkansas [Member]
Securities Held	The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $407.7 $11.8 $0.9 2018 Debt Securities $381.3 $0.6 $8.2
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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $51.5 $0.8 More than 12 months 21.0 0.1 Total $72.5 $0.9 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $65.8 $0.5 More than 12 months 231.1 7.7 Total $296.9 $8.2
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $50.3 $32.5 1 year - 5 years 120.4 170.3 5 years - 10 years 144.5 114.0 10 years - 15 years 24.3 10.3 15 years - 20 years 14.2 8.1 20 years+ 54.0 46.1 Total $407.7 $381.3
Entergy Louisiana [Member]
Securities Held	The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $593.4 $32.6 $0.3 2018 Debt Securities $532.9 $4.1 $6.0
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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $49.3 $0.3 More than 12 months 12.9 — Total $62.2 $0.3 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $170.1 $2.1 More than 12 months 145.8 3.9 Total $315.9 $6.0
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $56.6 $31.1 1 year - 5 years 138.2 130.5 5 years - 10 years 118.4 111.0 10 years - 15 years 34.7 29.0 15 years - 20 years 45.0 37.1 20 years+ 200.5 194.2 Total $593.4 $532.9
System Energy [Member]
Securities Held	The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $395.3 $19.7 $0.1 2018 Debt Securities $364.2 $2.9 $5.8
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 have been in a continuous loss position, are as follows as of September 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $38.8 $0.1 More than 12 months 4.3 — Total $43.1 $0.1 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $89.7 $2.4 More than 12 months 79.8 3.4 Total $169.5 $5.8
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $11.2 $22.8 1 year - 5 years 187.7 188.0 5 years - 10 years 92.7 73.4 10 years - 15 years 3.0 5.2 15 years - 20 years 5.9 10.2 20 years+ 94.8 64.6 Total $395.3 $364.2

Income Taxes Income Taxes (Tabl

Income Taxes Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2019
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 Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (In Millions) Entergy $96 $283 $219 $562 Entergy Arkansas $41 $153 $99 $260 Entergy Louisiana $17 $55 $31 $86 Entergy Mississippi $— $32 $— $161 Entergy New Orleans $7 $9 $9 $9 Entergy Texas $31 $— $73 $— System Entergy $— $34 $7 $46
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 Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (In Millions) Entergy $96 $283 $219 $562 Entergy Arkansas $41 $153 $99 $260 Entergy Louisiana $17 $55 $31 $86 Entergy Mississippi $— $32 $— $161 Entergy New Orleans $7 $9 $9 $9 Entergy Texas $31 $— $73 $— System Entergy $— $34 $7 $46
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 Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (In Millions) Entergy $96 $283 $219 $562 Entergy Arkansas $41 $153 $99 $260 Entergy Louisiana $17 $55 $31 $86 Entergy Mississippi $— $32 $— $161 Entergy New Orleans $7 $9 $9 $9 Entergy Texas $31 $— $73 $— System Entergy $— $34 $7 $46
Entergy Mississippi [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 Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (In Millions) Entergy $96 $283 $219 $562 Entergy Arkansas $41 $153 $99 $260 Entergy Louisiana $17 $55 $31 $86 Entergy Mississippi $— $32 $— $161 Entergy New Orleans $7 $9 $9 $9 Entergy Texas $31 $— $73 $— System Entergy $— $34 $7 $46
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 Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (In Millions) Entergy $96 $283 $219 $562 Entergy Arkansas $41 $153 $99 $260 Entergy Louisiana $17 $55 $31 $86 Entergy Mississippi $— $32 $— $161 Entergy New Orleans $7 $9 $9 $9 Entergy Texas $31 $— $73 $— System Entergy $— $34 $7 $46
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 Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (In Millions) Entergy $96 $283 $219 $562 Entergy Arkansas $41 $153 $99 $260 Entergy Louisiana $17 $55 $31 $86 Entergy Mississippi $— $32 $— $161 Entergy New Orleans $7 $9 $9 $9 Entergy Texas $31 $— $73 $— System Entergy $— $34 $7 $46
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 Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 (In Millions) Entergy $96 $283 $219 $562 Entergy Arkansas $41 $153 $99 $260 Entergy Louisiana $17 $55 $31 $86 Entergy Mississippi $— $32 $— $161 Entergy New Orleans $7 $9 $9 $9 Entergy Texas $31 $— $73 $— System Entergy $— $34 $7 $46

Revenue Recognition Revenue Rec

Revenue Recognition Revenue Recognition (Tables)	9 Months Ended
	Sep. 30, 2019
Disaggregation of Revenue [Table Text Block]	Entergy’s total revenues for the three months ended September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,154,455 $1,138,744 Commercial 722,334 693,760 Industrial 686,122 682,823 Governmental 61,697 60,647 Total billed retail 2,624,608 2,575,974 Sales for resale (a) 63,082 76,247 Other electric revenues (b) 115,352 42,847 Non-customer revenues (c) 9,892 2,819 Total electric revenues 2,812,934 2,697,887 Natural gas 27,269 26,352 Entergy Wholesale Commodities: Competitive businesses sales (a) 282,420 407,763 Non-customer revenues (c) 17,952 (27,683 ) Total competitive businesses 300,372 380,080 Total operating revenues $3,140,575 $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $2,727,367 $2,799,539 Commercial 1,871,416 1,871,380 Industrial 1,928,857 1,904,828 Governmental 172,280 173,949 Total billed retail 6,699,920 6,749,696 Sales for resale (a) 222,834 214,984 Other electric revenues (b) 326,771 289,668 Non-customer revenues (c) 30,158 22,026 Total electric revenues 7,279,683 7,276,374 Natural gas 112,916 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 923,288 1,148,460 Non-customer revenues (c) 100,480 (40,854 ) Total competitive businesses 1,023,768 1,107,606 Total operating revenues $8,416,367 $8,496,970
Entergy Arkansas [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $253,627 $426,012 $177,785 $81,468 $215,563 Commercial 162,564 277,071 131,596 56,430 94,673 Industrial 156,024 376,595 44,054 8,613 100,836 Governmental 5,907 18,731 12,551 19,030 5,478 Total billed retail 578,122 1,098,409 365,986 165,541 416,550 Sales for resale (a) 58,953 81,664 9,569 6,876 16,704 Other electric revenues (b) 47,085 37,521 20,499 2,537 9,177 Non-customer revenues (c) 3,366 4,280 2,678 1,784 446 Total electric revenues 687,526 1,221,874 398,732 176,738 442,877 Natural gas — 9,803 — 17,466 — Total operating revenues $687,526 $1,231,677 $398,732 $194,204 $442,877 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $621,208 $980,443 $423,395 $192,165 $510,156 Commercial 412,697 715,983 331,785 156,152 254,799 Industrial 396,515 1,108,193 120,490 24,353 279,306 Governmental 15,776 53,547 33,108 53,916 15,933 Total billed retail 1,446,196 2,858,166 908,778 426,586 1,060,194 Sales for resale (a) 213,038 248,827 19,377 25,680 48,251 Other electric revenues (b) 107,599 130,269 47,887 8,093 37,329 Non-customer revenues (c) 9,434 15,564 7,671 4,414 1,157 Total electric revenues 1,776,267 3,252,826 983,713 464,773 1,146,931 Natural gas — 44,498 — 68,418 — Total operating revenues $1,776,267 $3,297,324 $983,713 $533,191 $1,146,931 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (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) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy Louisiana [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $253,627 $426,012 $177,785 $81,468 $215,563 Commercial 162,564 277,071 131,596 56,430 94,673 Industrial 156,024 376,595 44,054 8,613 100,836 Governmental 5,907 18,731 12,551 19,030 5,478 Total billed retail 578,122 1,098,409 365,986 165,541 416,550 Sales for resale (a) 58,953 81,664 9,569 6,876 16,704 Other electric revenues (b) 47,085 37,521 20,499 2,537 9,177 Non-customer revenues (c) 3,366 4,280 2,678 1,784 446 Total electric revenues 687,526 1,221,874 398,732 176,738 442,877 Natural gas — 9,803 — 17,466 — Total operating revenues $687,526 $1,231,677 $398,732 $194,204 $442,877 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $621,208 $980,443 $423,395 $192,165 $510,156 Commercial 412,697 715,983 331,785 156,152 254,799 Industrial 396,515 1,108,193 120,490 24,353 279,306 Governmental 15,776 53,547 33,108 53,916 15,933 Total billed retail 1,446,196 2,858,166 908,778 426,586 1,060,194 Sales for resale (a) 213,038 248,827 19,377 25,680 48,251 Other electric revenues (b) 107,599 130,269 47,887 8,093 37,329 Non-customer revenues (c) 9,434 15,564 7,671 4,414 1,157 Total electric revenues 1,776,267 3,252,826 983,713 464,773 1,146,931 Natural gas — 44,498 — 68,418 — Total operating revenues $1,776,267 $3,297,324 $983,713 $533,191 $1,146,931 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (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) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy Mississippi [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $253,627 $426,012 $177,785 $81,468 $215,563 Commercial 162,564 277,071 131,596 56,430 94,673 Industrial 156,024 376,595 44,054 8,613 100,836 Governmental 5,907 18,731 12,551 19,030 5,478 Total billed retail 578,122 1,098,409 365,986 165,541 416,550 Sales for resale (a) 58,953 81,664 9,569 6,876 16,704 Other electric revenues (b) 47,085 37,521 20,499 2,537 9,177 Non-customer revenues (c) 3,366 4,280 2,678 1,784 446 Total electric revenues 687,526 1,221,874 398,732 176,738 442,877 Natural gas — 9,803 — 17,466 — Total operating revenues $687,526 $1,231,677 $398,732 $194,204 $442,877 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $621,208 $980,443 $423,395 $192,165 $510,156 Commercial 412,697 715,983 331,785 156,152 254,799 Industrial 396,515 1,108,193 120,490 24,353 279,306 Governmental 15,776 53,547 33,108 53,916 15,933 Total billed retail 1,446,196 2,858,166 908,778 426,586 1,060,194 Sales for resale (a) 213,038 248,827 19,377 25,680 48,251 Other electric revenues (b) 107,599 130,269 47,887 8,093 37,329 Non-customer revenues (c) 9,434 15,564 7,671 4,414 1,157 Total electric revenues 1,776,267 3,252,826 983,713 464,773 1,146,931 Natural gas — 44,498 — 68,418 — Total operating revenues $1,776,267 $3,297,324 $983,713 $533,191 $1,146,931 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (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) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy New Orleans [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $253,627 $426,012 $177,785 $81,468 $215,563 Commercial 162,564 277,071 131,596 56,430 94,673 Industrial 156,024 376,595 44,054 8,613 100,836 Governmental 5,907 18,731 12,551 19,030 5,478 Total billed retail 578,122 1,098,409 365,986 165,541 416,550 Sales for resale (a) 58,953 81,664 9,569 6,876 16,704 Other electric revenues (b) 47,085 37,521 20,499 2,537 9,177 Non-customer revenues (c) 3,366 4,280 2,678 1,784 446 Total electric revenues 687,526 1,221,874 398,732 176,738 442,877 Natural gas — 9,803 — 17,466 — Total operating revenues $687,526 $1,231,677 $398,732 $194,204 $442,877 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $621,208 $980,443 $423,395 $192,165 $510,156 Commercial 412,697 715,983 331,785 156,152 254,799 Industrial 396,515 1,108,193 120,490 24,353 279,306 Governmental 15,776 53,547 33,108 53,916 15,933 Total billed retail 1,446,196 2,858,166 908,778 426,586 1,060,194 Sales for resale (a) 213,038 248,827 19,377 25,680 48,251 Other electric revenues (b) 107,599 130,269 47,887 8,093 37,329 Non-customer revenues (c) 9,434 15,564 7,671 4,414 1,157 Total electric revenues 1,776,267 3,252,826 983,713 464,773 1,146,931 Natural gas — 44,498 — 68,418 — Total operating revenues $1,776,267 $3,297,324 $983,713 $533,191 $1,146,931 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (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) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy Texas [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $253,627 $426,012 $177,785 $81,468 $215,563 Commercial 162,564 277,071 131,596 56,430 94,673 Industrial 156,024 376,595 44,054 8,613 100,836 Governmental 5,907 18,731 12,551 19,030 5,478 Total billed retail 578,122 1,098,409 365,986 165,541 416,550 Sales for resale (a) 58,953 81,664 9,569 6,876 16,704 Other electric revenues (b) 47,085 37,521 20,499 2,537 9,177 Non-customer revenues (c) 3,366 4,280 2,678 1,784 446 Total electric revenues 687,526 1,221,874 398,732 176,738 442,877 Natural gas — 9,803 — 17,466 — Total operating revenues $687,526 $1,231,677 $398,732 $194,204 $442,877 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $621,208 $980,443 $423,395 $192,165 $510,156 Commercial 412,697 715,983 331,785 156,152 254,799 Industrial 396,515 1,108,193 120,490 24,353 279,306 Governmental 15,776 53,547 33,108 53,916 15,933 Total billed retail 1,446,196 2,858,166 908,778 426,586 1,060,194 Sales for resale (a) 213,038 248,827 19,377 25,680 48,251 Other electric revenues (b) 107,599 130,269 47,887 8,093 37,329 Non-customer revenues (c) 9,434 15,564 7,671 4,414 1,157 Total electric revenues 1,776,267 3,252,826 983,713 464,773 1,146,931 Natural gas — 44,498 — 68,418 — Total operating revenues $1,776,267 $3,297,324 $983,713 $533,191 $1,146,931 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (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) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Leases Leases (Tables)

Leases Leases (Tables)	9 Months Ended
	Sep. 30, 2019
Lease, Cost	Entergy incurred the following total lease costs for the three months ended September 30, 2019: (In Thousands) Operating lease cost $16,086 Financing lease cost: Amortization of right-of-use assets $2,945 Interest on lease liabilities $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019: (In Thousands) Operating lease cost $47,061 Financing lease cost: Amortization of right-of-use assets $10,837 Interest on lease liabilities $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019.
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019: (In Thousands) Current liabilities: Operating leases $52,348 Financing leases $11,482 Non-current liabilities: Operating leases $184,404 Financing leases $53,252
Lease, Terms and Discount Rate	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms: Operating leases 5.10 Financing leases 6.79 Weighted average discount rate: Operating leases 3.91 % Financing leases 4.67 %
Lease, Maturity	Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $16,088 $3,608 2020 59,965 13,521 2021 53,791 11,973 2022 45,391 10,775 2023 35,050 9,664 Years thereafter 56,906 26,889 Minimum lease payments 267,191 76,430 Less: amount representing interest 30,438 11,696 Present value of net minimum lease payments $236,753 $64,734
Operating And Capital Leases Future Minimum Payments Due	As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere): Year Operating Leases Capital Leases (In Thousands) 2019 $94,043 $2,887 2020 82,191 2,887 2021 75,147 2,887 2022 60,808 2,887 2023 47,391 2,887 Years thereafter 88,004 16,117 Minimum lease payments 447,584 30,552 Less: Amount representing interest — 8,555 Present value of net minimum lease payments $447,584 $21,997
Purchase Power Agreement Minimum Lease Payments	The minimum lease payments under the power purchase agreement are as follows: Year Entergy Texas (a) Entergy (In Thousands) 2019 $31,159 $31,159 2020 31,876 31,876 2021 32,609 32,609 2022 10,180 10,180 Minimum lease payments $105,824 $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas.
Entergy Arkansas [Member]
Lease, Cost	The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,306 $3,003 $1,752 $349 $1,074 Financing lease cost: Amortization of right-of-use assets $621 $1,014 $369 $178 $335 Interest on lease liabilities $105 $161 $65 $29 $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $9,724 $8,854 $5,220 $1,058 $3,135 Financing lease cost: Amortization of right-of-use assets $2,448 $4,014 $1,408 $696 $965 Interest on lease liabilities $408 $612 $241 $114 $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019.
Lease, Assets	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $49,503 $34,248 $18,149 $3,894 $13,074 Financing leases $11,094 $16,795 $6,994 $2,913 $5,515
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,662 $9,969 $6,137 $1,138 $3,427 Financing leases $2,600 $3,860 $1,473 $626 $1,252 Non-current liabilities: Operating leases $38,881 $24,289 $12,254 $2,755 $9,689 Financing leases $8,665 $12,925 $5,521 $2,286 $4,221
Lease, Terms and Discount Rate	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.09 4.28 4.65 3.99 4.49 Financing leases 5.44 5.41 5.41 5.72 5.25 Weighted average discount rate: Operating leases 3.75 % 3.74 % 3.77 % 3.94 % 3.86 % Financing leases 3.75 % 3.75 % 3.71 % 3.93 % 3.84 %
Lease, Maturity	Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $3,168 $2,863 $1,968 $332 $1,022 2020 11,756 10,518 6,066 1,196 4,014 2021 9,911 8,787 4,937 939 3,279 2022 7,613 6,068 3,503 659 2,338 2023 6,341 4,079 1,376 497 1,994 Years thereafter 16,421 4,702 2,642 729 2,193 Minimum lease payments 55,210 37,017 20,492 4,352 14,840 Less: amount representing interest 5,667 2,759 2,101 459 1,724 Present value of net minimum lease payments $49,543 $34,258 $18,391 $3,893 $13,116 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $713 $1,135 $429 $204 $375 2020 2,654 4,191 1,655 660 1,364 2021 2,258 3,536 1,490 549 1,171 2022 1,969 3,096 1,297 499 965 2023 1,728 2,635 1,078 451 827 Years thereafter 2,905 3,818 1,740 881 1,316 Minimum lease payments 12,227 18,411 7,689 3,244 6,018 Less: amount representing interest 961 1,626 695 332 545 Present value of net minimum lease payments $11,266 $16,785 $6,994 $2,912 $5,473
Operating And Capital Leases Future Minimum Payments Due	As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $20,421 $25,970 $9,344 $2,493 $5,744 2020 13,918 21,681 8,763 2,349 4,431 2021 11,931 19,514 7,186 1,901 3,625 2022 9,458 15,756 5,675 1,314 2,218 2023 7,782 12,092 2,946 1,043 1,561 Years thereafter 23,297 22,003 4,417 2,323 2,726 Minimum lease payments $86,807 $117,016 $38,331 $11,423 $20,305
Schedule of Rent Expense	Rental Expenses Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2018 $6.2 $20.2 $4.6 $2.5 $3.1 $1.9 2017 $7.5 $23.0 $5.6 $2.5 $3.4 $2.2 2016 $8.0 $17.8 $4.0 $0.9 $2.8 $1.6
Entergy Louisiana [Member]
Lease, Cost	The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,306 $3,003 $1,752 $349 $1,074 Financing lease cost: Amortization of right-of-use assets $621 $1,014 $369 $178 $335 Interest on lease liabilities $105 $161 $65 $29 $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $9,724 $8,854 $5,220 $1,058 $3,135 Financing lease cost: Amortization of right-of-use assets $2,448 $4,014 $1,408 $696 $965 Interest on lease liabilities $408 $612 $241 $114 $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019.
Lease, Assets	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $49,503 $34,248 $18,149 $3,894 $13,074 Financing leases $11,094 $16,795 $6,994 $2,913 $5,515
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,662 $9,969 $6,137 $1,138 $3,427 Financing leases $2,600 $3,860 $1,473 $626 $1,252 Non-current liabilities: Operating leases $38,881 $24,289 $12,254 $2,755 $9,689 Financing leases $8,665 $12,925 $5,521 $2,286 $4,221
Lease, Terms and Discount Rate	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.09 4.28 4.65 3.99 4.49 Financing leases 5.44 5.41 5.41 5.72 5.25 Weighted average discount rate: Operating leases 3.75 % 3.74 % 3.77 % 3.94 % 3.86 % Financing leases 3.75 % 3.75 % 3.71 % 3.93 % 3.84 %
Lease, Maturity	Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $3,168 $2,863 $1,968 $332 $1,022 2020 11,756 10,518 6,066 1,196 4,014 2021 9,911 8,787 4,937 939 3,279 2022 7,613 6,068 3,503 659 2,338 2023 6,341 4,079 1,376 497 1,994 Years thereafter 16,421 4,702 2,642 729 2,193 Minimum lease payments 55,210 37,017 20,492 4,352 14,840 Less: amount representing interest 5,667 2,759 2,101 459 1,724 Present value of net minimum lease payments $49,543 $34,258 $18,391 $3,893 $13,116 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $713 $1,135 $429 $204 $375 2020 2,654 4,191 1,655 660 1,364 2021 2,258 3,536 1,490 549 1,171 2022 1,969 3,096 1,297 499 965 2023 1,728 2,635 1,078 451 827 Years thereafter 2,905 3,818 1,740 881 1,316 Minimum lease payments 12,227 18,411 7,689 3,244 6,018 Less: amount representing interest 961 1,626 695 332 545 Present value of net minimum lease payments $11,266 $16,785 $6,994 $2,912 $5,473
Operating And Capital Leases Future Minimum Payments Due	As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $20,421 $25,970 $9,344 $2,493 $5,744 2020 13,918 21,681 8,763 2,349 4,431 2021 11,931 19,514 7,186 1,901 3,625 2022 9,458 15,756 5,675 1,314 2,218 2023 7,782 12,092 2,946 1,043 1,561 Years thereafter 23,297 22,003 4,417 2,323 2,726 Minimum lease payments $86,807 $117,016 $38,331 $11,423 $20,305
Schedule of Rent Expense	Rental Expenses Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2018 $6.2 $20.2 $4.6 $2.5 $3.1 $1.9 2017 $7.5 $23.0 $5.6 $2.5 $3.4 $2.2 2016 $8.0 $17.8 $4.0 $0.9 $2.8 $1.6
Entergy Mississippi [Member]
Lease, Cost	The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,306 $3,003 $1,752 $349 $1,074 Financing lease cost: Amortization of right-of-use assets $621 $1,014 $369 $178 $335 Interest on lease liabilities $105 $161 $65 $29 $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $9,724 $8,854 $5,220 $1,058 $3,135 Financing lease cost: Amortization of right-of-use assets $2,448 $4,014 $1,408 $696 $965 Interest on lease liabilities $408 $612 $241 $114 $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019.
Lease, Assets	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $49,503 $34,248 $18,149 $3,894 $13,074 Financing leases $11,094 $16,795 $6,994 $2,913 $5,515
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,662 $9,969 $6,137 $1,138 $3,427 Financing leases $2,600 $3,860 $1,473 $626 $1,252 Non-current liabilities: Operating leases $38,881 $24,289 $12,254 $2,755 $9,689 Financing leases $8,665 $12,925 $5,521 $2,286 $4,221
Lease, Terms and Discount Rate	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.09 4.28 4.65 3.99 4.49 Financing leases 5.44 5.41 5.41 5.72 5.25 Weighted average discount rate: Operating leases 3.75 % 3.74 % 3.77 % 3.94 % 3.86 % Financing leases 3.75 % 3.75 % 3.71 % 3.93 % 3.84 %
Lease, Maturity	Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $3,168 $2,863 $1,968 $332 $1,022 2020 11,756 10,518 6,066 1,196 4,014 2021 9,911 8,787 4,937 939 3,279 2022 7,613 6,068 3,503 659 2,338 2023 6,341 4,079 1,376 497 1,994 Years thereafter 16,421 4,702 2,642 729 2,193 Minimum lease payments 55,210 37,017 20,492 4,352 14,840 Less: amount representing interest 5,667 2,759 2,101 459 1,724 Present value of net minimum lease payments $49,543 $34,258 $18,391 $3,893 $13,116 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $713 $1,135 $429 $204 $375 2020 2,654 4,191 1,655 660 1,364 2021 2,258 3,536 1,490 549 1,171 2022 1,969 3,096 1,297 499 965 2023 1,728 2,635 1,078 451 827 Years thereafter 2,905 3,818 1,740 881 1,316 Minimum lease payments 12,227 18,411 7,689 3,244 6,018 Less: amount representing interest 961 1,626 695 332 545 Present value of net minimum lease payments $11,266 $16,785 $6,994 $2,912 $5,473
Operating And Capital Leases Future Minimum Payments Due	As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $20,421 $25,970 $9,344 $2,493 $5,744 2020 13,918 21,681 8,763 2,349 4,431 2021 11,931 19,514 7,186 1,901 3,625 2022 9,458 15,756 5,675 1,314 2,218 2023 7,782 12,092 2,946 1,043 1,561 Years thereafter 23,297 22,003 4,417 2,323 2,726 Minimum lease payments $86,807 $117,016 $38,331 $11,423 $20,305
Schedule of Rent Expense	Rental Expenses Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2018 $6.2 $20.2 $4.6 $2.5 $3.1 $1.9 2017 $7.5 $23.0 $5.6 $2.5 $3.4 $2.2 2016 $8.0 $17.8 $4.0 $0.9 $2.8 $1.6
Entergy New Orleans [Member]
Lease, Cost	The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,306 $3,003 $1,752 $349 $1,074 Financing lease cost: Amortization of right-of-use assets $621 $1,014 $369 $178 $335 Interest on lease liabilities $105 $161 $65 $29 $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $9,724 $8,854 $5,220 $1,058 $3,135 Financing lease cost: Amortization of right-of-use assets $2,448 $4,014 $1,408 $696 $965 Interest on lease liabilities $408 $612 $241 $114 $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019.
Lease, Assets	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $49,503 $34,248 $18,149 $3,894 $13,074 Financing leases $11,094 $16,795 $6,994 $2,913 $5,515
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,662 $9,969 $6,137 $1,138 $3,427 Financing leases $2,600 $3,860 $1,473 $626 $1,252 Non-current liabilities: Operating leases $38,881 $24,289 $12,254 $2,755 $9,689 Financing leases $8,665 $12,925 $5,521 $2,286 $4,221
Lease, Terms and Discount Rate	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.09 4.28 4.65 3.99 4.49 Financing leases 5.44 5.41 5.41 5.72 5.25 Weighted average discount rate: Operating leases 3.75 % 3.74 % 3.77 % 3.94 % 3.86 % Financing leases 3.75 % 3.75 % 3.71 % 3.93 % 3.84 %
Lease, Maturity	Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $3,168 $2,863 $1,968 $332 $1,022 2020 11,756 10,518 6,066 1,196 4,014 2021 9,911 8,787 4,937 939 3,279 2022 7,613 6,068 3,503 659 2,338 2023 6,341 4,079 1,376 497 1,994 Years thereafter 16,421 4,702 2,642 729 2,193 Minimum lease payments 55,210 37,017 20,492 4,352 14,840 Less: amount representing interest 5,667 2,759 2,101 459 1,724 Present value of net minimum lease payments $49,543 $34,258 $18,391 $3,893 $13,116 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $713 $1,135 $429 $204 $375 2020 2,654 4,191 1,655 660 1,364 2021 2,258 3,536 1,490 549 1,171 2022 1,969 3,096 1,297 499 965 2023 1,728 2,635 1,078 451 827 Years thereafter 2,905 3,818 1,740 881 1,316 Minimum lease payments 12,227 18,411 7,689 3,244 6,018 Less: amount representing interest 961 1,626 695 332 545 Present value of net minimum lease payments $11,266 $16,785 $6,994 $2,912 $5,473
Operating And Capital Leases Future Minimum Payments Due	As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $20,421 $25,970 $9,344 $2,493 $5,744 2020 13,918 21,681 8,763 2,349 4,431 2021 11,931 19,514 7,186 1,901 3,625 2022 9,458 15,756 5,675 1,314 2,218 2023 7,782 12,092 2,946 1,043 1,561 Years thereafter 23,297 22,003 4,417 2,323 2,726 Minimum lease payments $86,807 $117,016 $38,331 $11,423 $20,305
Schedule of Rent Expense	Rental Expenses Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2018 $6.2 $20.2 $4.6 $2.5 $3.1 $1.9 2017 $7.5 $23.0 $5.6 $2.5 $3.4 $2.2 2016 $8.0 $17.8 $4.0 $0.9 $2.8 $1.6
Entergy Texas [Member]
Lease, Cost	The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,306 $3,003 $1,752 $349 $1,074 Financing lease cost: Amortization of right-of-use assets $621 $1,014 $369 $178 $335 Interest on lease liabilities $105 $161 $65 $29 $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $9,724 $8,854 $5,220 $1,058 $3,135 Financing lease cost: Amortization of right-of-use assets $2,448 $4,014 $1,408 $696 $965 Interest on lease liabilities $408 $612 $241 $114 $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019.
Lease, Assets	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $49,503 $34,248 $18,149 $3,894 $13,074 Financing leases $11,094 $16,795 $6,994 $2,913 $5,515
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,662 $9,969 $6,137 $1,138 $3,427 Financing leases $2,600 $3,860 $1,473 $626 $1,252 Non-current liabilities: Operating leases $38,881 $24,289 $12,254 $2,755 $9,689 Financing leases $8,665 $12,925 $5,521 $2,286 $4,221
Lease, Terms and Discount Rate	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.09 4.28 4.65 3.99 4.49 Financing leases 5.44 5.41 5.41 5.72 5.25 Weighted average discount rate: Operating leases 3.75 % 3.74 % 3.77 % 3.94 % 3.86 % Financing leases 3.75 % 3.75 % 3.71 % 3.93 % 3.84 %
Lease, Maturity	Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $3,168 $2,863 $1,968 $332 $1,022 2020 11,756 10,518 6,066 1,196 4,014 2021 9,911 8,787 4,937 939 3,279 2022 7,613 6,068 3,503 659 2,338 2023 6,341 4,079 1,376 497 1,994 Years thereafter 16,421 4,702 2,642 729 2,193 Minimum lease payments 55,210 37,017 20,492 4,352 14,840 Less: amount representing interest 5,667 2,759 2,101 459 1,724 Present value of net minimum lease payments $49,543 $34,258 $18,391 $3,893 $13,116 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $713 $1,135 $429 $204 $375 2020 2,654 4,191 1,655 660 1,364 2021 2,258 3,536 1,490 549 1,171 2022 1,969 3,096 1,297 499 965 2023 1,728 2,635 1,078 451 827 Years thereafter 2,905 3,818 1,740 881 1,316 Minimum lease payments 12,227 18,411 7,689 3,244 6,018 Less: amount representing interest 961 1,626 695 332 545 Present value of net minimum lease payments $11,266 $16,785 $6,994 $2,912 $5,473
Operating And Capital Leases Future Minimum Payments Due	As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $20,421 $25,970 $9,344 $2,493 $5,744 2020 13,918 21,681 8,763 2,349 4,431 2021 11,931 19,514 7,186 1,901 3,625 2022 9,458 15,756 5,675 1,314 2,218 2023 7,782 12,092 2,946 1,043 1,561 Years thereafter 23,297 22,003 4,417 2,323 2,726 Minimum lease payments $86,807 $117,016 $38,331 $11,423 $20,305
Schedule of Rent Expense	Rental Expenses Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2018 $6.2 $20.2 $4.6 $2.5 $3.1 $1.9 2017 $7.5 $23.0 $5.6 $2.5 $3.4 $2.2 2016 $8.0 $17.8 $4.0 $0.9 $2.8 $1.6
Purchase Power Agreement Minimum Lease Payments	The minimum lease payments under the power purchase agreement are as follows: Year Entergy Texas (a) Entergy (In Thousands) 2019 $31,159 $31,159 2020 31,876 31,876 2021 32,609 32,609 2022 10,180 10,180 Minimum lease payments $105,824 $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas.
System Energy [Member]
Schedule of Rent Expense	Rental Expenses Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2018 $6.2 $20.2 $4.6 $2.5 $3.1 $1.9 2017 $7.5 $23.0 $5.6 $2.5 $3.4 $2.2 2016 $8.0 $17.8 $4.0 $0.9 $2.8 $1.6
Present Value Of Future Minimum Lease Payments Sale Leaseback Transactions	As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352

Commitments and Contingencies C

Commitments and Contingencies Commitments and Contingencies (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended	9 Months Ended
	Aug. 31, 2019	Sep. 30, 2019	Sep. 30, 2018
Loss Contingencies [Line Items]
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		$ 2,369	$ 0
Entergy Louisiana [Member]
Loss Contingencies [Line Items]
Litigation Settlement, Amount Awarded from Other Party	$ 19,000
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	12,000
Damages awarded for previously recorded operation and maintenance	5,000
Damages awarded for previously recorded nuclear fuel expense	$ 2,000
System Energy [Member]
Loss Contingencies [Line Items]
Minimum Rate Of Equity Capital		35.00%

Rate And Regulatory Matters (Na

Rate And Regulatory Matters (Narrative) (Details) - USD ($)	Jul. 31, 2019	Oct. 31, 2019	Sep. 30, 2019	Aug. 31, 2019	Jul. 31, 2019	Jun. 30, 2019	May 31, 2019	Apr. 30, 2019	Mar. 31, 2019	Jan. 31, 2019	Dec. 31, 2018	Jul. 31, 2018	Dec. 31, 2019	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2019	Mar. 31, 2019	Dec. 31, 2018	Jul. 27, 2019	Apr. 23, 2018	Mar. 31, 2019
Regulatory Assets [Line Items]
Impairment of Long-Lived Assets Held-for-use														$ 225,175,000	$ 210,263,000
Deferred Fuel Cost			$ 0								$ 27,251,000			0						$ 27,251,000
Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount							$ 118,700,000
Rate Increase Included in Formula Rate Plan							109,500,000
Earned return on common equity																				10.61%
Formula rate plan revenue decrease																				$ 8,900,000
Entergy Louisiana [Member] | Revenue Subject to Refund [Member]
Regulatory Assets [Line Items]
LPSC staff recommended fuel adjustment clause refund including interest										$ 7,300,000
Entergy Louisiana calculated fuel adjustment clause refund including interest				$ 4,200,000
Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Deferred Fuel Cost			0								8,016,000			$ 0						$ 8,016,000
Authorized return on common equity														6.93%						7.13%
Public Utilities, Requested Return on Equity, Percentage														6.94%
Public Utilities, Requested Rate Increase (Decrease), Amount																				$ 10,100,000
Public Utilities, Approved Rate Increase (Decrease), Amount																				$ 11,000,000
Earned return on common equity																				7.81%
Monthly storm damage provision														$ 1,750,000
Authorized Storm Damage Reserve Balance			15,000,000											15,000,000
Balance At Which Storm Damage Accrual Will Return To Current Level							$ 10,000,000							10,000,000
Entergy Mississippi [Member] | Revenue Subject to Refund [Member]
Regulatory Assets [Line Items]
Provision recorded to reflect change in formula rate plan revenues compared to allowed rate of return											9,300,000									$ 9,300,000
True-up to provision recorded to reflect change in formula rate plan revenues compared to allowed rate of return						$ 900,000			$ 800,000										$ 800,000				$ 800,000
Entergy Mississippi [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount																		$ 36,800,000
Public Utilities, Approved Rate Increase (Decrease), Amount																		$ 32,800,000
Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount				30,000,000
Entergy New Orleans [Member] | Electricity [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount				27,000,000
Entergy New Orleans [Member] | Natural Gas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount				$ 3,000,000
Entergy New Orleans [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage				10.50%
Entergy New Orleans [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount		$ 39,000,000
Entergy New Orleans [Member] | Subsequent Event [Member] | Electricity [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount		36,000,000
Entergy New Orleans [Member] | Subsequent Event [Member] | Natural Gas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount		$ 3,000,000
Entergy New Orleans [Member] | Subsequent Event [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage		9.35%
Public Utilities, Approved Equity Capital Structure, Percentage		50.00%
Entergy Texas [Member]
Regulatory Assets [Line Items]
Jurisdictional eligible fuel and purchased power expenses, net of credits																							1,600,000,000
Fuel and purchased power under-recovery balance including interest									25,800,000										25,800,000				$ 25,800,000
Requested recovery of internal and external litigation expenses previously paid or incurred										$ 7,200,000
Entergy Texas [Member] | Minimum [Member]
Regulatory Assets [Line Items]
Recommended disallowance of requested recovery of expenses previously paid or incurred								$ 3,200,000
Entergy Texas [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Recommended disallowance of requested recovery of expenses previously paid or incurred								$ 4,200,000
Entergy Texas [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Recommended disallowance of requested recovery of expenses previously paid or incurred		$ 1,400,000
Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Deferred Fuel Cost			0								19,235,000			0						19,235,000
Public Utilities, Requested Return on Equity, Percentage	9.75%
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 15,300,000
Refund to Customers Credited Through Formula Rate Plan																				46,600,000
Regulatory asset related to scrubber costs incurred at White Bluff plant	$ 11,200,000				$ 11,200,000
Energy Cost Recovery Rider Rate Per kWh																			$ 0.01882
Retail balance over-recovery											100,000									100,000
Receipts from utility operating companies pursuant to FERC order												$ 4,200,000
Entergy Arkansas [Member] | Revenue Subject to Refund [Member]
Regulatory Assets [Line Items]
Provision recorded to reflect change in formula rate plan revenues compared to allowed rate of return											35,100,000									35,100,000
True-up to provision recorded to reflect change in formula rate plan revenues compared to allowed rate of return			11,500,000											11,500,000
Entergy Arkansas [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount		14,000,000
Projected Revenue Deficiency																$ 61,900,000
Public Utilities, Approved Rate Increase (Decrease), Amount		10,100,000
Regulatory charge recorded to write-off White Bluff scrubber regulatory asset													$ 11,200,000
Energy Cost Recovery Rider Rate Per kWh																	$ 0.01462
System Energy [Member]
Regulatory Assets [Line Items]
FERC requested authorized return on equity for System Energy in return on equity proceeding																						9.89%
Public utilities requested return on equity percentage, median 2nd refund period																					9.65%
Public utilities requested return on equity percentage, midpoint 2nd refund period																					9.74%
Modified public utilities requested return on equity percentage based on benchmarks, median 2nd refund period																					9.91%
Modified public utilities requested return on equity percentage based on benchmarks, midpoint 2nd refund period																					10.30%
LPSC requested authorized return on equity for System Energy in return on equity proceeding																					7.97%	7.81%
APSC/MPSC revised argued authorized return on equity for System Energy in return on equity proceeding																					8.32%	8.26%
FERC requested authorized return on equity for System Energy in return on equity proceeding, rebuttal																					9.63%	9.40%
APSC/MPSC requested authorized return on equity for System Energy in return on equity proceeding																					8.41%	8.24%
Annual renewal lease payments on Grand Gulf Sale-Leaseback														17,200,000
LPSC requested rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback											334,500,000									$ 334,500,000
FERC staff argued over-recovery in depreciation expense for capital additions				$ 32,000,000
LPSC requested refund of cost of capital additions resulting from Grand Gulf sale-leaseback			$ 274,800,000											$ 274,800,000
Ratepayer savings due to Grand Gulf sale-leaseback initial and renewal terms						$ 850,000,000
FERC requested rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback				$ 602,000,000
System Energy [Member] | Minimum [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage																					10.32%	10.10%
System Energy [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage																					10.69%	10.70%
Percent Equity in Proposed Common Equity Ratio				37.00%
Percent Debt in Proposed Common Equity Ratio				63.00%
LPSC Argued Equity Capital Structure, Percentage				49.00%
APSC and MPSC Argued Equity Capital Structure, Percentage				35.98%
APSC and MPSC Alternative Argued Equity Capital Structure, Percentage				46.75%
FERC Percent Equity in Proposed Common Equity Ratio			46.74%
FERC Percent Debt in Proposed Common Equity Ratio			53.26%
System Energy [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
LPSC requested rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback		512,000,000
FERC requested rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback		$ 511,000,000
Grand Gulf [Member] | System Energy [Member]
Regulatory Assets [Line Items]
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage														11.50%
FERC May 2018 Order [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Receipts from utility operating companies pursuant to FERC order												23,000,000
FERC May 2018 Order [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Receipts from utility operating companies pursuant to FERC order												$ 4,000,000
Distribution Cost Recovery Factor Rider [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount									$ 3,200,000
Transmission Cost Recovery Factor Rider [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount				$ 19,400,000							$ 2,700,000
Revenue increase resulting from incremental revenue				$ 16,700,000
Public Utilities, Approved Rate Increase (Decrease), Amount					$ 2,700,000

Rate And Regulatory Matters R_2

Rate And Regulatory Matters Rate and Regulatory Matters (Payments/Receipts Among The Utility Operating Companies) (Details) - USD ($) $ in Millions	1 Months Ended
	Jul. 31, 2018	Feb. 29, 2016
Entergy Arkansas [Member]
Receipts from utility operating companies pursuant to FERC order	$ (4.2)
FERC May 2018 Order [Member] | Entergy Arkansas [Member]
Receipts from utility operating companies pursuant to FERC order	(4)
FERC May 2018 Order [Member] | Entergy Louisiana [Member]
Receipts from utility operating companies pursuant to FERC order	(23)
FERC May 2018 Order [Member] | Entergy Mississippi [Member]
Payments to utility operating companies pursuant to FERC order	16
FERC May 2018 Order [Member] | Entergy New Orleans [Member]
Payments to utility operating companies pursuant to FERC order	5
FERC May 2018 Order [Member] | Entergy Texas [Member]
Payments to utility operating companies pursuant to FERC order	$ 6
FERC December 2015 Order [Member] | Entergy Arkansas [Member]
Payments to utility operating companies pursuant to FERC order		$ 2
FERC December 2015 Order [Member] | Entergy Louisiana [Member]
Payments to utility operating companies pursuant to FERC order		6
FERC December 2015 Order [Member] | Entergy Mississippi [Member]
Receipts from utility operating companies pursuant to FERC order		(4)
FERC December 2015 Order [Member] | Entergy New Orleans [Member]
Receipts from utility operating companies pursuant to FERC order		(1)
FERC December 2015 Order [Member] | Entergy Texas [Member]
Receipts from utility operating companies pursuant to FERC order		$ (3)

Equity (Narrative) (Details)

Equity (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	Oct. 25, 2019	Sep. 30, 2019	May 31, 2019	Dec. 31, 2018	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Oct. 15, 2024	Jan. 01, 2019	Jun. 30, 2018	Jan. 01, 2018
Equity [Abstract]
Stock Options Excluded From Diluted Common Shares Outstanding Calculation						1,100,000	200,000	1,100,000
Forward Contract Indexed to Issuer's Equity, Indexed Shares											15,300,000
Proceeds from Issuance of Common Stock			$ 608,000	$ 500,000			$ 607,650	$ 0
Shares, Issued		1,582,916			1,582,916		1,582,916
Common stock dividend (in dollars per share)					$ 0.91	$ 0.89	$ 2.73	$ 2.67
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax										$ 6,806		$ 632,617
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets										0		$ (56,360)
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects								$ 15,505
Accounting Standards Update 2017-12 [Member]
Equity [Abstract]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets										8,000
Accounting Standards Update 2017-08 [Member]
Equity [Abstract]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets										$ 1,000
Common Stock [Member]
Equity [Abstract]
Forward Contract Indexed to Issuer's Equity, Shares			8,448,171	6,834,221
Subsequent Event [Member]
Equity [Abstract]
Common stock dividend (in dollars per share)	$ 0.93
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Entergy Texas [Member]
Proceeds from Issuance of Preferred Stock and Preference Stock		$ 35,000			$ 35,000		$ 35,000
Preferred Stock, Dividend Rate, Percentage		5.375%					5.375%
Preferred Stock, Shares Issued		1,400,000			1,400,000		1,400,000
Equity [Abstract]
Preferred Stock, Liquidation Preference Per Share		$ 25			$ 25		$ 25
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Subsequent Event [Member] | Entergy Texas [Member]
Equity [Abstract]
Preferred Stock, Liquidation Preference Per Share									$ 25

Equity (Schedule Of Earnings Pe

Equity (Schedule Of Earnings Per Share, Basic And Diluted) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Incremental Weighted Average Shares Attributable to Dilutive Effect [Abstract]
Stock options, Shares	700,000	400,000	500,000	300,000
Stock options $/share	$ (0.01)	$ (0.01)	$ (0.01)	$ (0.01)
Restricted stock, Shares	900,000	800,000	700,000	700,000
Restricted stock $/share	$ (0.01)	$ (0.01)	$ (0.02)	$ (0.01)
Incremental Common Shares Attributable to Dilutive Effect of Equity Forward Agreements	0	1,500,000	600,000	900,000
Average Dilutive Effect Of Equity Forwards	$ 0	$ (0.02)	$ (0.01)	$ (0.03)
Basic earnings per share
Net Income (Loss) Available to Common Stockholders, Basic	$ 365,240	$ 536,379	$ 856,201	$ 914,560
Net Income (Loss) Available to Common Stockholders, Diluted	$ 365,200	$ 536,400	$ 856,200	$ 914,600
Net Income Attributable to Entergy Corporation, Shares	198,932,387	181,002,303	193,876,557	180,845,440
Net Income Attributable to Entergy Corporation, $/share	$ 1.84	$ 2.96	$ 4.42	$ 5.06
Diluted earnings per share, Shares	200,492,935	183,664,583	195,685,851	182,692,325
Diluted earnings per share $/share	$ 1.82	$ 2.92	$ 4.38	$ 5.01

Equity (Accumulated Other Compr

Equity (Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018	Jan. 01, 2019	Dec. 31, 2018	Jan. 01, 2018	Dec. 31, 2017
Accumulated Other Comprehensive Income (Loss) [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets									$ 0		$ (56,360)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	$ (419,772)	$ (430,404)		$ (632,126)	$ (613,642)		$ (419,772)	$ (632,126)		$ (557,173)		$ (23,531)
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax									(6,806)		(632,617)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	3,160			(47,574)			160,205	(82,774)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	7,472			29,090			(15,998)	91,291
Other comprehensive income (loss)	10,632	120,748	$ 12,827	(18,484)	(52,144)	$ 79,145	144,207	8,517
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect						(16,538)
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects								15,505
Accumulated Net Investment Gain (Loss) Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	32,007	26,736		(10,587)	(8,842)		32,007	(10,587)		(2,116)		545,045
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax									879		(632,617)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	8,350			(7,173)			37,724	(50,958)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(3,079)			5,428			(4,480)	13,716
Other comprehensive income (loss)	5,271			(1,745)			33,244	(37,242)
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects								114,227
Accumulated Other Comprehensive Income [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets									(6,806)		(632,617)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other comprehensive income (loss)	10,632	120,748	12,827	(18,484)	(52,144)	79,145
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect						15,505
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	(483,412)	(508,876)		(574,661)	(589,926)		(483,412)	(574,661)		(531,922)		(531,099)
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax									0		0
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0			0			0	0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	25,464			15,265			48,510	47,404
Other comprehensive income (loss)	25,464			15,265			48,510	47,404
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects								(90,966)
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	31,633	51,736		(46,878)	(14,874)		31,633	(46,878)		(23,135)		(37,477)
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax									(7,685)		0
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(5,190)			(40,401)			122,481	(31,816)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(14,913)			8,397			(60,028)	30,171
Other comprehensive income (loss)	(20,103)			(32,004)			62,453	(1,645)
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects								(7,756)
Entergy Louisiana [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	(9,060)						(9,060)			(6,153)
Other comprehensive income (loss)	(969)	(969)	(969)	(500)	(501)	(501)	(2,907)	(1,502)
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect						(3,787)
Entergy Louisiana [Member] | Accumulated Other Comprehensive Income [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other comprehensive income (loss)	(969)	(969)	$ (969)	(500)	(501)	(501)
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect						$ (10,049)
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	(9,060)	$ (8,091)		(57,951)	$ (57,451)		(9,060)	(57,951)		$ (6,153)		$ (46,400)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(969)			(500)			(2,907)	(1,502)
Other comprehensive income (loss)	$ (969)			$ (500)			(2,907)	(1,502)
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects							$ 0	$ (10,049)
Restatement Adjustment [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss									(563,979)		(656,148)
Restatement Adjustment [Member] | Accumulated Net Investment Gain (Loss) Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss									(1,237)		(87,572)
Restatement Adjustment [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss									(531,922)		(531,099)
Restatement Adjustment [Member] | Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss									$ (30,820)		$ (37,477)

Equity (Reclassification out of

Equity (Reclassification out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 3,140,575			$ 3,104,319			$ 8,416,367	$ 8,496,970
Other Nonoperating Income (Expense)	(50,086)			(43,591)			(160,614)	(123,439)
Income taxes (benefits)	(29,201)			283,006			(73,430)	519,937
Consolidated net income	369,459	$ 240,533	$ 258,646	539,818	$ 248,860	$ 136,200	868,639	924,877
Competitive Businesses [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	300,372			380,080			1,023,768	1,107,606
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Consolidated net income	(7,472)			(29,090)			15,998	(91,291)
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)			(63)			(145)	(278)
INCOME (LOSS) BEFORE INCOME TAXES	18,877			(10,629)			75,984	(38,191)
Income taxes (benefits)	(3,964)			2,232			(15,956)	8,020
Consolidated net income	14,913			(8,397)			60,028	(30,171)
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	18,925			(10,566)			76,129	(37,913)
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]
Realized gain (loss)	4,872			(8,589)			7,088	(21,703)
Income taxes (benefits)	(1,793)			3,161			(2,608)	7,987
Consolidated net income	3,079			(5,428)			4,480	(13,716)
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	5,325			5,425			15,977	16,278
Amortization of loss	(20,919)			(24,740)			(58,888)	(74,503)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	(16,630)			(76)			(18,685)	(2,098)
INCOME (LOSS) BEFORE INCOME TAXES	(32,224)			(19,391)			(61,596)	(60,323)
Income taxes (benefits)	6,760			4,126			13,086	12,919
Consolidated net income	(25,464)			(15,265)			(48,510)	(47,404)
Entergy Louisiana [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,231,677			1,206,612			3,297,324	3,308,744
Other Nonoperating Income (Expense)	(15,067)			(25,782)			(79,717)	(56,217)
Income taxes (benefits)	(54,964)			(2,944)			(109,900)	30,430
Consolidated net income	255,260	$ 183,084	$ 127,633	218,308	$ 184,358	$ 111,593	565,977	514,260
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	1,837			1,934			5,511	5,802
Amortization of loss	(526)			(1,257)			(1,578)	(3,770)
INCOME (LOSS) BEFORE INCOME TAXES	1,311			677			3,933	2,032
Income taxes (benefits)	(342)			(177)			(1,026)	(530)
Consolidated net income	$ 969			$ 500			$ 2,907	$ 1,502

Revolving Credit Facilities, _3

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended					9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Feb. 28, 2019	Jan. 31, 2019	Sep. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Short-term borrowings	$ 1,917,788					$ 1,917,788	$ 1,942,339
Amount of Facility	3,500,000					3,500,000
Amount Drawn/ Outstanding	$ 155,000					$ 155,000
Commercial Paper Program [Member]
Debt Instrument [Line Items]
Debt, weighted average interest rate	2.88%					2.88%
Commercial Paper program limit	$ 2,000,000					$ 2,000,000
Commercial Paper Amount Outstanding	1,918,000					1,918,000
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						3.94%
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
Entergy Arkansas [Member] | Mortgage Bonds Four Point Two Percent Series Due April 2049 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt			$ 350,000
Debt instrument, interest rate, stated percentage			4.20%
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
Entergy Louisiana [Member] | Mortgage Bonds, Four Point Two Zero Percent Series due April Twenty Fifty [Member] [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt			$ 525,000
Debt instrument, interest rate, stated percentage			4.20%
Entergy Mississippi [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings	175,000					175,000
Letters of Credit Outstanding, Amount	200					200	200
Entergy Mississippi [Member] | Mortgage bonds, 3.85% Series due June 2049 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt		$ 300,000
Debt instrument, interest rate, stated percentage		3.85%
Entergy Mississippi [Member] | Mortgage Bonds Six Point Six Four Percent Series Due July Two Thousand Nineteen [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		6.64%
Repayments of Debt		$ 150,000
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							$ 4,100
Entergy Texas [Member] | Mortgage Bonds Four Percent Due March 2029 [Domain]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt					$ 300,000
Debt instrument, interest rate, stated percentage					4.00%
Entergy Texas [Member] | Mortgage Bonds Four Point Five Percent Due March 2039 [Domain] [Domain]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt					$ 400,000
Debt instrument, interest rate, stated percentage					4.50%
Entergy Texas [Member] | 7.125% Series First Mortgage Bonds Due February 2019 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				7.125%
Repayments of Debt				$ 500,000
Entergy Texas [Member] | Mortgage Bonds Three Point Fifty Five Percent Due September 2049 [Domain]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt	$ 300,000
Debt instrument, interest rate, stated percentage	3.55%					3.55%
System Energy [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings	$ 200,000					$ 200,000
System Energy [Member] | Two Point Five Percent Series 2019 Revenue Refunding Bonds Due April 2022 [Domain]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt			$ 134,000
Debt instrument, interest rate, stated percentage			2.50%
System Energy [Member] | Two Point Five Percent Series 2019 Revenue Refunding Bonds Due April 2022 [Domain]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			5.875%
Repayments of Debt			$ 134,000
Entergy Nuclear Vermont Yankee [Member]
Debt Instrument [Line Items]
Amount of Facility	139,000					$ 139,000
Line of credit facility, commitment fee percentage						0.20%
Amount Drawn/ Outstanding	139,000				$ 139,000	$ 139,000
Line of Credit Facility, Interest Rate During Period						4.07%
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
System Energy VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding	53,600					$ 53,600
Line of Credit Facility, Interest Rate During Period						3.42%
Line of credit facility commitment fee as a percentage of undrawn commitment amount						0.10%
Line of Credit Facility, Expiration Date						Sep. 16, 2021
Entergy Arkansas VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding	$ 30,300					$ 30,300
Line of Credit Facility, Interest Rate During Period						3.41%
Line of credit facility commitment fee as a percentage of undrawn commitment amount						0.10%
Line of Credit Facility, Expiration Date						Sep. 16, 2021
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%
Entergy Louisiana Waterford VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding	$ 65,500					$ 65,500
Line of Credit Facility, Interest Rate During Period						3.41%
Line of credit facility commitment fee as a percentage of undrawn commitment amount						0.10%
Line of Credit Facility, Expiration Date						Sep. 16, 2021
Entergy Louisiana Waterford VIE [Member] | Three Point Nine Two Percent Series H Dues February Two Thousand Twenty One [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	3.92%					3.92%
Entergy Louisiana River Bend VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding	$ 84,300					$ 84,300
Line of Credit Facility, Interest Rate During Period						3.37%
Line of credit facility commitment fee as a percentage of undrawn commitment amount						0.10%
Line of Credit Facility, Expiration Date						Sep. 16, 2021
Maximum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment fee percentage						0.225%
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 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 Twenty Million [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Amount of Facility	$ 20,000					$ 20,000
Letters of Credit Outstanding, Amount	0					0
Amount Drawn/ Outstanding	0					$ 0
Line of Credit Facility, Interest Rate During Period						3.17%
Line of Credit Facility, Expiration Date						Apr. 30, 2020
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						3.17%
Line of Credit Facility, Expiration Date						Sep. 14, 2024
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						3.17%
Line of Credit Facility, Expiration Date						Sep. 14, 2024
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						3.54%
Line of Credit Facility, Expiration Date						Sep. 14, 2024
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						3.54%
Line of Credit Facility, Expiration Date						May 31, 2020
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						3.54%
Line of Credit Facility, Expiration Date						May 31, 2020
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						3.54%
Line of Credit Facility, Expiration Date						May 31, 2020
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	800					800
Amount Drawn/ Outstanding	$ 0					$ 0
Line of Credit Facility, Interest Rate During Period						3.32%
Line of Credit Facility, Expiration Date						Nov. 20, 2021

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	Sep. 30, 2019USD ($)
Summary of the borrowings outstanding and capacity available under the facility
Capacity	$ 3,500
Amount Drawn/ Outstanding	155
Letters of Credit	6
Capacity Available	$ 3,339

Revolving Credit Facilities, _5

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Credit Facilities) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Amount of Facility	$ 3,500,000
Amount Drawn/ Outstanding	155,000
Entergy Arkansas [Member]
Amount of total borrowing capacity against which fronting commitments exist	$ 5,000
Entergy Arkansas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Sep. 14, 2024
Amount of Facility	$ 150,000
Interest Rate	3.17%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Arkansas [Member] | Credit Facility Of Twenty Million [Member]
Expiration Date	Apr. 30, 2020
Amount of Facility	$ 20,000
Interest Rate	3.17%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Louisiana [Member]
Amount of total borrowing capacity against which fronting commitments exist	$ 15,000
Entergy Louisiana [Member] | Credit Facility Of Three Hundred Fifty Million [Member]
Expiration Date	Sep. 14, 2024
Amount of Facility	$ 350,000
Interest Rate	3.17%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	$ 200	$ 200
Entergy Mississippi [Member] | Credit Facility Of Thirty Seven Point Five Million [Member]
Expiration Date	May 31, 2020
Amount of Facility	$ 37,500
Interest Rate	3.54%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Thirty Five Million [Member]
Expiration Date	May 31, 2020
Amount of Facility	$ 35,000
Interest Rate	3.54%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Ten Million [Member]
Expiration Date	May 31, 2020
Amount of Facility	$ 10,000
Interest Rate	3.54%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy New Orleans [Member]
Amount of total borrowing capacity against which fronting commitments exist	$ 10,000
Entergy New Orleans [Member] | Credit Facility Of Twenty Five Million [Member]
Expiration Date	Nov. 20, 2021
Amount of Facility	$ 25,000
Interest Rate	3.32%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	800
Entergy Texas [Member]
Amount of total borrowing capacity against which fronting commitments exist	$ 30,000
Letters of Credit Outstanding, Amount		$ 4,100
Entergy Texas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Sep. 14, 2024
Amount of Facility	$ 150,000
Interest Rate	3.54%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 1,300

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	Sep. 30, 2019USD ($)
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	0
Entergy New Orleans [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	150
Borrowings	46
Entergy Texas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	0
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	9 Months Ended
	Sep. 30, 2019USD ($)
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount Drawn/ Outstanding	$ 155
Entergy Arkansas VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Sep. 16, 2021
Amount of Facility	$ 80
Line of Credit Facility, Interest Rate During Period	3.41%
Amount Drawn/ Outstanding	$ 30.3
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
Expiration Date	Sep. 16, 2021
Amount of Facility	$ 120
Line of Credit Facility, Interest Rate During Period	3.42%
Amount Drawn/ Outstanding	$ 53.6
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
Expiration Date	Sep. 16, 2021
Amount of Facility	$ 105
Line of Credit Facility, Interest Rate During Period	3.37%
Amount Drawn/ Outstanding	$ 84.3
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
Expiration Date	Sep. 16, 2021
Amount of Facility	$ 105
Line of Credit Facility, Interest Rate During Period	3.41%
Amount Drawn/ Outstanding	$ 65.5
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	Sep. 30, 2019USD ($)
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 Three Eight Percent Series R Notes Due August Two Thousand Twenty [Member] | Entergy Louisiana River Bend VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.38%
Amount	$ 70
Three Point Nine Two Percent Series H Dues February Two Thousand Twenty One [Member] | Entergy Louisiana Waterford VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.92%
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
Three Point Four Two Percent Series J Notes Due April Two Thousand Twenty One [Member] | System Energy VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.42%
Amount	$ 100

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	Sep. 30, 2019	Dec. 31, 2018
Long-term Debt, Fair Value	$ 18,628,268	$ 15,880,239
Long-term Debt, Book Value	17,458,026	16,168,312
Entergy Arkansas [Member]
Long-term Debt, Fair Value	3,621,073	3,002,627
Long-term Debt, Book Value	3,538,384	3,225,759
Long term DOE obligations	190,000	187,000
Entergy Louisiana [Member]
Long-term Debt, Fair Value	8,038,675	6,834,134
Long-term Debt, Book Value	7,344,160	6,805,768
Entergy Mississippi [Member]
Long-term Debt, Fair Value	1,586,199	1,276,452
Long-term Debt, Book Value	1,469,454	1,325,750
Entergy New Orleans [Member]
Long-term Debt, Fair Value	522,688	491,569
Long-term Debt, Book Value	478,619	483,704
Entergy Texas [Member]
Long-term Debt, Fair Value	2,128,842	1,528,828
Long-term Debt, Book Value	1,938,303	1,513,735
System Energy [Member]
Long-term Debt, Fair Value	554,374	596,123
Long-term Debt, Book Value	570,001	630,750
Capital Lease Obligations	$ 34,000	$ 34,000

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	Sep. 30, 2019	Dec. 31, 2018
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	$ 0.2	$ 0.2
Entergy Texas [Member]
Letters of Credit Outstanding, Amount		$ 4.1
Credit Facility Of Twenty Five Million [Member] | Entergy Arkansas [Member]
Uncommitted Credit Facility	$ 25
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 1
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	$ 26.2
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	0.70%
Letters of Credit Outstanding, Amount	$ 11.7
Credit Facility of Sixty Five Million [Member] | Entergy Mississippi [Member]
Uncommitted Credit Facility	$ 65
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 8.1

Stock Based Compensation (Narra

Stock Based Compensation (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	3 Months Ended	9 Months Ended
	Jan. 31, 2019	Mar. 31, 2019	Sep. 30, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period of awards under Entergy's plans, years			3 years
Equity Ownership And Long Term Cash Incentive Plan Two Thousand Fifteen [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option granted (in shares)		693,161
Weighted-average grant-date fair value of options granted (in dollars per share)		$ 8.32
Stock options outstanding			2,515,896
Weighted-average exercise price of stock options outstanding (in dollars per share)			$ 78.53
Intrinsic value in the money stock options			$ 97.7
Restricted Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period of awards under Entergy's plans, years			3 years
Restricted Awards [Member] | Equity Ownership And Long Term Cash Incentive Plan Two Thousand Fifteen [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock awards granted	355,537
Restricted stock awards granted value (in dollars per share)	$ 89.19
Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period of awards under Entergy's plans, years			3 years
Long Term Incentive Plan [Member] | Equity Ownership And Long Term Cash Incentive Plan Two Thousand Fifteen [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Long-term incentive plan awards	180,824
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] | Equity Ownership And Long Term Cash Incentive Plan Two Thousand Fifteen [Member] | 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)	$ 102.07
Long Term Incentive Plan [Member] | Equity Ownership And Long Term Cash Incentive Plan Two Thousand Fifteen [Member] | 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)	$ 89.19

Stock-Based Compensation (Finan

Stock-Based Compensation (Financial Information For Stock Options) (Details) - Employee Stock Option [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 0.9	$ 1.1	$ 2.9	$ 3.3
Tax benefit recognized in Entergy's net income	0.2	0.2	0.7	0.8
Compensation cost capitalized as part of fixed assets and inventory	$ 0.4	$ 0.1	$ 1	$ 0.5

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		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 8.4	$ 8.5	$ 25.6	$ 26
Tax benefit recognized in Entergy's net income	2.1	2.2	6.5	6.6
Compensation cost capitalized as part of fixed assets and inventory	$ 3	$ 2.5	$ 8.8	$ 7.3

Retirement And Other Postreti_3

Retirement And Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended			9 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		$ 176,900		$ 176,900
Defined Benefit Plan, Plan Assets, Contributions by Employer				123,100
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		27,112		27,112
Defined Benefit Plan, Plan Assets, Contributions by Employer				18,222
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		26,451		26,451
Defined Benefit Plan, Plan Assets, Contributions by Employer				18,272
Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		7,701		7,701
Defined Benefit Plan, Plan Assets, Contributions by Employer				5,186
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		1,800		1,800
Defined Benefit Plan, Plan Assets, Contributions by Employer				1,237
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		1,645		1,645
Defined Benefit Plan, Plan Assets, Contributions by Employer				1,192
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		8,285		8,285
Defined Benefit Plan, Plan Assets, Contributions by Employer				5,631
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	$ 8,890
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	8,179
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	2,515
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	563
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	453
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	$ 2,654
Non Qualified Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs		4,600	$ 4,200	16,300	$ 19,700
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits		955	212	4,600	7,000
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs		67	114	211	369
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits			7		30
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs		38	42	122	138
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs		69	73	257	230
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits				40
Non Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs		5	20	16	62
Non Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs		$ 119	$ 122	$ 365	529
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits					$ 139

Retirement And Other Postreti_4

Retirement And Other Postretirement Benefits (Components Of Qualified Net Pension Cost) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	$ 33,553	$ 38,752	$ 100,766	$ 116,256
Interest cost on projected benefit obligation	73,261	66,854	221,114	200,562
Expected return on assets	(103,751)	(110,535)	(311,494)	(331,605)
Amortization of prior service cost (credit)	0	99	0	297
Amortization of loss	60,395	68,526	177,233	205,578
Net other postretirement benefit cost	79,749	63,696	205,210	191,088
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	16,291	0	17,591	0
Pension Plans Defined Benefit [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	5,260	6,189	15,782	18,567
Interest cost on projected benefit obligation	14,175	13,004	42,525	39,012
Expected return on assets	(20,177)	(21,851)	(60,529)	(65,553)
Amortization of loss	11,840	13,412	35,522	40,236
Net other postretirement benefit cost	11,098	10,754	33,300	32,262
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	7,284	8,446	21,852	25,338
Interest cost on projected benefit obligation	15,882	14,940	47,646	44,820
Expected return on assets	(22,651)	(24,809)	(67,955)	(74,427)
Amortization of loss	11,643	14,450	34,929	43,350
Net other postretirement benefit cost	12,158	13,027	36,472	39,081
Pension Plans Defined Benefit [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,629	1,822	4,887	5,466
Interest cost on projected benefit obligation	4,068	3,769	12,204	11,307
Expected return on assets	(5,969)	(6,502)	(17,905)	(19,506)
Amortization of loss	3,104	3,610	9,313	10,830
Net other postretirement benefit cost	2,832	2,699	8,499	8,097
Pension Plans Defined Benefit [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	568	673	1,706	2,019
Interest cost on projected benefit obligation	1,873	1,813	5,621	5,439
Expected return on assets	(2,696)	(2,993)	(8,089)	(8,979)
Amortization of loss	1,529	1,954	4,588	5,862
Net other postretirement benefit cost	1,274	1,447	3,826	4,341
Pension Plans Defined Benefit [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,350	1,589	4,050	4,767
Interest cost on projected benefit obligation	3,613	3,348	10,837	10,044
Expected return on assets	(5,862)	(6,523)	(17,586)	(19,569)
Amortization of loss	2,334	2,626	7,002	7,878
Net other postretirement benefit cost	1,435	1,040	4,303	3,120
Pension Plans Defined Benefit [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,549	1,776	4,649	5,328
Interest cost on projected benefit obligation	3,364	3,227	10,091	9,681
Expected return on assets	(4,678)	(4,991)	(14,032)	(14,973)
Amortization of loss	2,850	3,715	8,550	11,145
Net other postretirement benefit cost	3,085	3,727	9,258	11,181
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	4,675	6,782	14,025	20,346
Interest cost on projected benefit obligation	11,975	12,681	35,925	38,043
Expected return on assets	(9,562)	(10,373)	(28,686)	(31,119)
Amortization of prior service cost (credit)	(8,844)	(9,251)	(26,532)	(27,753)
Amortization of loss	358	3,432	1,074	10,296
Net other postretirement benefit cost	(1,398)	3,271	(4,194)	9,813
Other Postretirement [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	591	793	1,773	2,379
Interest cost on projected benefit obligation	1,807	1,997	5,421	5,991
Expected return on assets	(3,991)	(4,342)	(11,973)	(13,026)
Amortization of prior service cost (credit)	(1,238)	(1,278)	(3,714)	(3,834)
Amortization of loss	144	289	432	867
Net other postretirement benefit cost	(2,687)	(2,541)	(8,061)	(7,623)
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,160	1,556	3,480	4,668
Interest cost on projected benefit obligation	2,666	2,789	7,998	8,367
Expected return on assets	0	0	0	0
Amortization of prior service cost (credit)	(1,837)	(1,934)	(5,511)	(5,802)
Amortization of loss	(174)	388	(522)	1,164
Net other postretirement benefit cost	1,815	2,799	5,445	8,397
Other Postretirement [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	262	321	786	963
Interest cost on projected benefit obligation	670	683	2,010	2,049
Expected return on assets	(1,199)	(1,303)	(3,597)	(3,909)
Amortization of prior service cost (credit)	(439)	(456)	(1,317)	(1,368)
Amortization of loss	181	377	543	1,131
Net other postretirement benefit cost	(525)	(378)	(1,575)	(1,134)
Other Postretirement [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	92	129	276	387
Interest cost on projected benefit obligation	395	417	1,185	1,251
Expected return on assets	(1,237)	(1,313)	(3,711)	(3,939)
Amortization of prior service cost (credit)	(171)	(186)	(513)	(558)
Amortization of loss	58	34	174	102
Net other postretirement benefit cost	(863)	(919)	(2,589)	(2,757)
Other Postretirement [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	236	330	708	990
Interest cost on projected benefit obligation	854	939	2,562	2,817
Expected return on assets	(2,276)	(2,446)	(6,828)	(7,338)
Amortization of prior service cost (credit)	(561)	(579)	(1,683)	(1,737)
Amortization of loss	121	206	363	618
Net other postretirement benefit cost	(1,626)	(1,550)	(4,878)	(4,650)
Other Postretirement [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	243	306	729	918
Interest cost on projected benefit obligation	476	500	1,428	1,500
Expected return on assets	(697)	(783)	(2,091)	(2,349)
Amortization of prior service cost (credit)	(363)	(378)	(1,089)	(1,134)
Amortization of loss	89	233	267	699
Net other postretirement benefit cost	(252)	(122)	(756)	(366)
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	4,600	4,200	16,300	19,700
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits	955	212	4,600	7,000
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	67	114	211	369
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits		7		30
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	38	42	122	138
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	69	73	257	230
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits			40
Non Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	5	20	16	62
Non Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	$ 119	$ 122	$ 365	529
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits				$ 139

Retirement And Other Postreti_5

Retirement And Other Postretirement Benefits (Expected Employer Contributions) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Dec. 31, 2019	Sep. 30, 2019
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		$ 176,900
Defined Benefit Plan, Plan Assets, Contributions by Employer		123,100
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		26,451
Defined Benefit Plan, Plan Assets, Contributions by Employer		18,272
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	$ 8,179
Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		7,701
Defined Benefit Plan, Plan Assets, Contributions by Employer		5,186
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	2,515
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		1,800
Defined Benefit Plan, Plan Assets, Contributions by Employer		1,237
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	563
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		1,645
Defined Benefit Plan, Plan Assets, Contributions by Employer		1,192
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	453
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		8,285
Defined Benefit Plan, Plan Assets, Contributions by Employer		5,631
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	2,654
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		27,112
Defined Benefit Plan, Plan Assets, Contributions by Employer		$ 18,222
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	$ 8,890

Retirement And Other Postreti_6

Retirement And Other Postretirement Benefits (Reclassification Out Of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	$ 5,325	$ 5,425	$ 15,977	$ 16,278
Amortization of loss	(20,919)	(24,740)	(58,888)	(74,503)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(16,630)	(76)	(18,685)	(2,098)
Total	(32,224)	(19,391)	(61,596)	(60,323)
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,837	1,934	5,511	5,802
Amortization of loss	(526)	(1,257)	(1,578)	(3,770)
Total	1,311	677	3,933	2,032
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	(99)	0	(297)
Amortization of loss	(20,686)	(21,958)	(58,156)	(65,870)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(16,257)	0	(17,557)	0
Total	(36,943)	(22,057)	(75,713)	(66,167)
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	(699)	(867)	(2,096)	(2,601)
Total	(699)	(867)	(2,096)	(2,601)
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	5,375	5,595	16,125	16,786
Amortization of loss	308	(1,932)	923	(5,801)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0	0	0	0
Total	5,683	3,663	17,048	10,985
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,837	1,934	5,511	5,802
Amortization of loss	174	(388)	522	(1,164)
Total	2,011	1,546	6,033	4,638
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(50)	(71)	(148)	(211)
Amortization of loss	(541)	(850)	(1,655)	(2,832)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(373)	(76)	(1,128)	(2,098)
Total	(964)	(997)	(2,931)	(5,141)
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)	(2)	(4)	(5)
Total	$ (1)	$ (2)	$ (4)	$ (5)

Business Segment Information Bu

Business Segment Information Business Segment Information (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended	29 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2019	Jun. 01, 2022
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Asset Write-Offs, Impairments, And Related Charges	$ 8	$ 155	$ 98	$ 297
Restructuring Charges	14	43	70	103
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges			70
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | Subsequent Event [Member]
Segment Reporting Information [Line Items]
Restructuring Charges					$ 100	$ 135
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	$ 14	$ 43	$ 70	$ 103

Business Segment Information (S

Business Segment Information (Segment Financial Information) (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 3,140,575			$ 3,104,319			$ 8,416,367	$ 8,496,970
Segment Financial Information
Income taxes (benefits)	29,201			(283,006)			73,430	(519,937)
Consolidated net income	369,459	$ 240,533	$ 258,646	539,818	$ 248,860	$ 136,200	868,639	924,877
Assets	50,506,268						50,506,268		$ 48,275,066
Utility [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,840,222			2,724,279			7,392,641	7,389,477
Segment Financial Information
Income taxes (benefits)	71,698			(137,035)			81,283	(325,134)
Consolidated net income	581,964			507,745			1,150,863	1,104,078
Assets	48,348,371						48,348,371		44,777,167
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	300,363			380,080			1,023,757	1,107,606
Segment Financial Information
Income taxes (benefits)	(30,855)			(135,659)			25,763	(166,882)
Consolidated net income	(140,501)			105,571			(68,804)	31,456
Assets	4,122,007						4,122,007		5,459,275
All Other [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	9			0			11	0
Segment Financial Information
Income taxes (benefits)	(11,642)			(10,312)			(33,616)	(27,921)
Consolidated net income	(40,105)			(41,601)			(117,725)	(114,962)
Assets	501,983						501,983		733,366
Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(19)			(40)			(42)	(113)
Segment Financial Information
Income taxes (benefits)	0			0			0	0
Consolidated net income	(31,899)			$ (31,897)			(95,695)	$ (95,695)
Assets	$ (2,466,093)						$ (2,466,093)		$ (2,694,742)

Business Segment Information _2

Business Segment Information Business Segment Information (Restructuring Costs) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Payments for Restructuring	$ 86	$ 0	$ 140	$ 0
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges			70
Payments for Restructuring	86	0	140	0
Economic Development Costs [Member]
Segment Reporting Information [Line Items]
Payments for Restructuring	0	0	0	0
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	14	43	70	103
Restructuring Reserve	123	200	123	200	$ 195	$ 193	$ 157	$ 97
Entergy Wholesale Commodities [Member] | Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	14	43	70	103
Restructuring Reserve	109	186	109	186	181	179	143	83
Entergy Wholesale Commodities [Member] | Economic Development Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	0	0	0	0
Restructuring Reserve	$ 14	$ 14	$ 14	$ 14	$ 14	$ 14	$ 14	$ 14

Risk Management and Fair Valu_3

Risk Management and Fair Values (Narrative) (Details) TWh in Millions, $ in Millions	3 Months Ended			9 Months Ended		12 Months Ended
	Dec. 31, 2019TWh	Sep. 30, 2019USD ($)GWhMMBTU	Sep. 30, 2018USD ($)	Sep. 30, 2019USD ($)GWhMMBTU	Sep. 30, 2018USD ($)	Dec. 31, 2018USD ($)counterparty
Risk Management and Fair Values [Abstract]
Cash flow hedges relating to power sales as part of net unrealized gains				$ 42
Reclassified from accumulated other comprehensive income (OCI) to operating revenues				30
Maturity of cash flow hedges, Tax		$ 4	$ (2)	$ 16	$ (8)
Maximum length of time over which Company is currently hedging the variability in future cash flows for forecasted power transactions, years				1 year 6 months
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		40,346,000		40,346,000
Total volume of fixed transmission rights outstanding | GWh		79,459		79,459
Change in cash flow hedges due to ineffectiveness			(3.1)		(5.2)
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset and Liability Unrealized Gains (Loss) Included in Earnings		$ (1.2)	$ 1.7	$ (4.7)	$ 1.1
Entergy Arkansas [Member]
Risk Management and Fair Values [Abstract]
Total volume of fixed transmission rights outstanding | GWh		17,898		17,898
Entergy Louisiana [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		32,880,000		32,880,000
Total volume of fixed transmission rights outstanding | GWh		36,474		36,474
Entergy Mississippi [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount		$ 0.2		$ 0.2		$ 0.2
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		6,210,000		6,210,000
Total volume of fixed transmission rights outstanding | GWh		10,087		10,087
Entergy New Orleans [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		1,256,000		1,256,000
Total volume of fixed transmission rights outstanding | GWh		3,751		3,751
Entergy Texas [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount						4.1
Total volume of fixed transmission rights outstanding | GWh		10,931		10,931
Gas Hedge Contracts [Member] | Entergy Louisiana [Member]
Risk Management and Fair Values [Abstract]
Maximum Length of Time Hedged in Cash Flow Hedge				4 years 6 months
Gas Hedge Contracts [Member] | Entergy Mississippi [Member]
Risk Management and Fair Values [Abstract]
Maximum Length of Time Hedged in Cash Flow Hedge				6 months
Entergy Wholesale Commodities [Member]
Risk Management and Fair Values [Abstract]
Cash collateral posted		$ 13		$ 13		$ 19
Derivative, Collateral, Obligation to Return Cash		2		2
Letters of Credit Held		$ 48		$ 48
Number of Derivative Contract Counterparties in a Liability Position | counterparty						6
Dollar amount of hedge contract in a liability position						$ 34
Utility [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount						$ 4
Subsequent Event [Member]
Risk Management and Fair Values [Abstract]
Planned generation sold forward from non utility nuclear power plants for the remainder of the period	97.00%
Planned Generation From Non Nuclear Power Plants Sold Forward Under Financial Hedges	72.00%
Total planned generation for remainder of the period | TWh	6.1

Risk Management and Fair Valu_4

Risk Management and Fair Values (Fair Values Of Derivative Instruments) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Utility [Member]
Liabilities:
Letters of Credit Outstanding, Amount		$ 4
Entergy Wholesale Commodities [Member]
Derivatives, Fair Value [Line Items]
Cash collateral posted	$ 13	19
Assets:
Derivative, Collateral, Obligation to Return Cash	(2)
Liabilities:
Letters of Credit Held	48
Other Non-Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	2	20
Derivative, Collateral, Right to Reclaim Cash	(2)	(7)
Derivative Liability	0	13
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] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	12	0
Derivative Asset, Fair Value, Gross Asset	14	7
Derivative, Collateral, Obligation to Return Cash	(2)	(7)
Other Deferred Debits And Other Assets [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [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
Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1	2
Derivative Asset, Fair Value, Gross Asset	1	2
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	30	0
Derivative Asset, Fair Value, Gross Asset	35	32
Derivative, Collateral, Obligation to Return Cash	(5)	(32)
Prepayments And Other [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	6	2
Derivative Asset, Fair Value, Gross Asset	9	4
Derivative, Collateral, Obligation to Return Cash	(3)	(2)
Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Utility and Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	16	15
Derivative Asset, Fair Value, Gross Asset	17	16
Derivative, Collateral, Obligation to Return Cash	(1)	(1)
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	5	54
Derivative, Collateral, Right to Reclaim Cash	(5)	(33)
Derivative Liability	0	21
Other Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	4	1
Derivative, Collateral, Right to Reclaim Cash	(4)	(1)
Derivative Liability	0	0
Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	4	1
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability	4	1
Entergy Louisiana [Member] | Other Non-Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	1.4
Derivative, Collateral, Right to Reclaim Cash	0
Derivative Liability	1.4
Entergy Louisiana [Member] | Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1	1.6
Derivative Asset, Fair Value, Gross Asset	1	1.6
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	0.1	0.3
Derivative Asset, Fair Value, Gross Asset	0.1	0.3
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	9.1	8.3
Derivative Asset, Fair Value, Gross Asset	9.1	8.4
Derivative, Collateral, Obligation to Return Cash	0	(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	2.2	1.1
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability	2.2	1.1
Entergy Mississippi [Member]
Liabilities:
Letters of Credit Outstanding, Amount	0.2	0.2
Entergy Mississippi [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1.5	2.2
Derivative Asset, Fair Value, Gross Asset	1.5	2.2
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	1.1
Derivative, Collateral, Right to Reclaim Cash	0
Derivative Liability	1.1
Entergy New Orleans [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0.7	1.3
Derivative Asset, Fair Value, Gross Asset	0.7	1.3
Derivative, Collateral, Obligation to Return Cash	0	0
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	0.1	0.1
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability	0.1	0.1
Entergy Arkansas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	3.9	3.4
Derivative Asset, Fair Value, Gross Asset	4	3.6
Derivative, Collateral, Obligation to Return Cash	(0.1)	(0.2)
Entergy Texas [Member]
Liabilities:
Letters of Credit Outstanding, Amount		4.1
Entergy Texas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1.3
Derivative Asset, Fair Value, Gross Asset	1.7
Derivative, Collateral, Obligation to Return Cash	$ (0.4)
Entergy Texas [Member] | Other Current Liabilities [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		0.9
Derivative, Collateral, Right to Reclaim Cash		(1.4)
Derivative Liability		$ (0.5)

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		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Effect of Derivative instruments designated as cash flow hedges on consolidated statements of income
Amount of gain (loss) recognized in AOCI (effective portion)	$ (7)	$ (51)	$ 145	$ (40)
Amount of gain reclassified from accumulated OCI into income (effective portion)	$ 19	$ (11)	$ 76	$ (38)

Risk Management and Fair Valu_6

Risk Management and Fair Values (Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income) (Details) - Not Designated As Hedging Instrument [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Competitive Businesses Operating Revenues [Member] | Electricity Swaps And Options [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recognized in AOCI	$ 0	$ 0	$ 0	$ 0
Amount of gain (loss) recorded in income	1	(2)	4	0
Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recognized in AOCI	0	0	0	0
Amount of gain (loss) recorded in income	(2)	0	(9)	5
Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recognized in AOCI	0	0	0	0
Amount of gain (loss) recorded in income	25	31	78	104
Entergy Arkansas [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	3.5	10.1	15.4	20.1
Entergy Louisiana [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	(1.7)	(0.7)	(3.6)	4.2
Entergy Louisiana [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	14.4	13.8	40.9	57.2
Entergy Mississippi [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	(0.3)	0.1	(5.5)	0.9
Entergy Mississippi [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	1.9	5.4	5.3	23
Entergy New Orleans [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	(0.1)		0.1
Entergy New Orleans [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	(0.3)	2	2.2	10.5
Entergy Texas [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	$ 5.5	$ (0.4)	$ 13.6	$ (5.6)

Risk Management and Fair Valu_7

Risk Management and Fair Values (Assets And Liabilities At Fair Value On A Recurring Basis) (Details) - USD ($)		Sep. 30, 2019	Dec. 31, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		$ 885,436,000	$ 424,285,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		55,000,000	51,000,000
Replacement Reserve Escrow		410,000,000	403,000,000
Equity Securities, FV-NI		836,000,000	1,686,000,000
Debt Securities		2,968,000,000	2,884,000,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		7,544,000,000	7,818,000,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure			35,000,000
Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		5,000,000	1,000,000
Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			34,000,000
Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities		2,325,000,000	2,350,000,000
Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		48,000,000	3,000,000
Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,000,000	2,000,000
Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		16,000,000	15,000,000
Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		885,000,000	424,000,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		55,000,000	51,000,000
Replacement Reserve Escrow		410,000,000	403,000,000
Equity Securities, FV-NI		836,000,000	1,686,000,000
Debt Securities		1,214,000,000	1,259,000,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		3,400,000,000	3,823,000,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure			1,000,000
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		4,000,000	1,000,000
Fair Value Inputs Level 1 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
Fair Value Inputs Level 1 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Replacement Reserve Escrow		0	0
Equity Securities, FV-NI		0	0
Debt Securities		1,754,000,000	1,625,000,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,755,000,000	1,627,000,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure			0
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		1,000,000	0
Fair Value, Inputs, Level 2 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
Fair Value, Inputs, Level 2 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,000,000	2,000,000
Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Replacement Reserve Escrow		0	0
Equity Securities, FV-NI		0	0
Debt Securities		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		64,000,000	18,000,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure			34,000,000
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	0
Fair Value, Inputs, Level 3 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			34,000,000
Fair Value, Inputs, Level 3 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		48,000,000	3,000,000
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		16,000,000	15,000,000
Entergy New Orleans [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	19,651,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		5,268,000	2,224,000
Replacement Reserve Escrow		82,200,000	80,900,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		88,200,000	104,100,000
Entergy New Orleans [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		100,000	100,000
Entergy New Orleans [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		700,000	1,300,000
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value			19,700,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		5,300,000	2,200,000
Replacement Reserve Escrow		82,200,000	80,900,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		87,500,000	102,800,000
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		100,000	100,000
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
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value			0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Replacement Reserve Escrow		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		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
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value			0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Replacement Reserve Escrow		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		700,000	1,300,000
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	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		700,000	1,300,000
Entergy Mississippi [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		98,925,000	36,943,000
Assets at fair value on a recurring basis
Replacement Reserve Escrow		33,000,000	32,400,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		133,400,000	71,500,000
Entergy Mississippi [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		1,100,000
Entergy Mississippi [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,500,000	2,200,000
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		98,900,000	36,900,000
Assets at fair value on a recurring basis
Replacement Reserve Escrow		33,000,000	32,400,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		131,900,000	69,300,000
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		1,100,000
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
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Replacement Reserve Escrow		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		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
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Replacement Reserve Escrow		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,500,000	2,200,000
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] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,500,000	2,200,000
Entergy Louisiana [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		127,821,000	43,112,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		10,100,000	3,600,000
Replacement Reserve Escrow		294,500,000	289,500,000
Equity Securities, FV-NI	[1]	5,300,000	13,300,000
Debt Securities	[1]	593,400,000	532,900,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,928,200,000	1,631,400,000
Entergy Louisiana [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		3,600,000	1,100,000
Entergy Louisiana [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	[2]	886,900,000	738,800,000
Entergy Louisiana [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,100,000	1,900,000
Entergy Louisiana [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		9,100,000	8,300,000
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		127,800,000	43,100,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		10,100,000	3,600,000
Replacement Reserve Escrow		294,500,000	289,500,000
Equity Securities, FV-NI	[1]	5,300,000	13,300,000
Debt Securities	[1]	183,700,000	162,000,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		621,500,000	511,500,000
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		2,200,000	700,000
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		100,000	0
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
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Replacement Reserve Escrow		0	0
Equity Securities, FV-NI	[1]	0	0
Debt Securities	[1]	409,700,000	370,900,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		410,700,000	372,800,000
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		1,400,000	400,000
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,000,000	1,900,000
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
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Replacement Reserve Escrow		0	0
Equity Securities, FV-NI	[1]	0	0
Debt Securities	[1]	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		9,100,000	8,300,000
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	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
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		9,100,000	8,300,000
Entergy Arkansas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		76,659,000	1,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		7,904,000	4,666,000
Equity Securities, FV-NI	[1]	6,200,000	4,000,000
Debt Securities	[1]	407,700,000	381,300,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,134,300,000	920,100,000
Entergy Arkansas [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	[2]	631,900,000	526,700,000
Entergy Arkansas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		3,900,000	3,400,000
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		76,700,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		7,900,000	4,700,000
Equity Securities, FV-NI	[1]	6,200,000	4,000,000
Debt Securities	[1]	101,400,000	94,800,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		192,200,000	103,500,000
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
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
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Equity Securities, FV-NI	[1]	0	0
Debt Securities	[1]	306,300,000	286,500,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		306,300,000	286,500,000
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
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
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Equity Securities, FV-NI	[1]	0	0
Debt Securities	[1]	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		3,900,000	3,400,000
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		3,900,000	3,400,000
Entergy Texas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		92,253,000	30,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		31,649,000	40,185,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		125,200,000
Entergy Texas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,300,000
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			500,000
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		92,300,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		31,600,000	40,200,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		123,900,000
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
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			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
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		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
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			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
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,300,000
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,300,000
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			500,000
System Energy [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		164,246,000	95,617,000
Assets at fair value on a recurring basis
Equity Securities, FV-NI	[1]	5,800,000	4,400,000
Debt Securities	[1]	395,300,000	364,200,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,166,500,000	965,100,000
System Energy [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	[2]	601,200,000	500,900,000
System Energy [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		164,200,000	95,600,000
Assets at fair value on a recurring basis
Equity Securities, FV-NI	[1]	5,800,000	4,400,000
Debt Securities	[1]	206,000,000	224,500,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		376,000,000	324,500,000
System Energy [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Equity Securities, FV-NI	[1]	0	0
Debt Securities	[1]	189,300,000	139,700,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		189,300,000	139,700,000
System Energy [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Equity Securities, FV-NI	[1]	0	0
Debt Securities	[1]	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		$ 0	$ 0
[1]	(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.
[2]	(b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

Risk Management and Fair Valu_8

Risk Management and Fair Values (Reconciliation Of Changes In The Net Assets (Liabilities) For The Fair Value Of Derivatives Classified As Level 3 In The Fair Value Hierarchy) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Dec. 31, 2017
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	$ 48		$ 48
Issuance of Financial Transmission Rights			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	48		48		$ 72
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value		$ (67)		(67)		$ (31)	$ (25)	$ (65)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	1		4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings		(4)		(5)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)			145
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Other Comprehensive Income (Loss)	(7)	(51)		(40)
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	(18)		(70)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements		13		43
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	16	29	16	29	29	15	41	21
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings				(1)
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	12	19	44	67
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(25)	(31)	(78)	(104)
Issuance of Financial Transmission Rights			35	46
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	3.9	11.3	3.9	11.3	8.2	3.4	10.5	3
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				16.6
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset		10.9	6.3
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included as Regulatory Liability/Asset	(0.8)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(3.5)	(10.1)	(15.4)	(20.1)
Issuance of Financial Transmission Rights			9.6	11.8
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	9.1	12	9.1	12	15.6	8.3	18.2	10.2
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				39
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	7.9	7.6	23
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(14.4)	(13.8)	(40.9)	(57.2)
Issuance of Financial Transmission Rights			18.7	20
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	1.5	3.7	1.5	3.7	2.8	2.2	4.4	2.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				20.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	0.6	4.7	0.6
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(1.9)	(5.4)	(5.2)	(23)
Issuance of Financial Transmission Rights			3.9	4.5
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	0.7	2.1	0.7	2.1	2	1.3	3	2.2
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				6.7
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset		1.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included as Regulatory Liability/Asset	(1.6)		(1.1)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements		(2)	(2.2)	(10.5)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	0.3
Issuance of Financial Transmission Rights			2.7	3.7
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	1.3	0.1	1.3	0.1	$ 0.6		$ 4.7	$ 3.4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value						$ (0.5)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings				(15)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	6.2		15.3
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included as Regulatory Liability/Asset		(5)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	$ (5.5)		(13.6)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements		$ 0.4		5.6
Issuance of Financial Transmission Rights			$ 0.1	$ 6.1

Risk Management and Fair Valu_9

Risk Management and Fair Values (Schedules Of Valuation Techniques) (Details) $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	$ 48
Maximum [Member]
Range from Average Percentage for Fair Value of Electricity Swaps	4.75%
Effect of Significant Unobservable Inputs on Fair Value of Electricity Swaps	$ 5
Minimum [Member]
Range from Average Percentage for Fair Value of Electricity Swaps	4.00%
Effect of Significant Unobservable Inputs on Fair Value of Electricity Swaps	$ 4
Gas Hedge Contracts [Member] | Entergy Louisiana [Member]
Maximum Length of Time Hedged in Cash Flow Hedge	4 years 6 months
Gas Hedge Contracts [Member] | Entergy Mississippi [Member]
Maximum Length of Time Hedged in Cash Flow Hedge	6 months

Decommissioning Trust Funds (Na

Decommissioning Trust Funds (Narrative) (Details) - USD ($)	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Aug. 31, 2019	Jan. 01, 2019	Jan. 01, 2018
Debt Securities, Trading, Measurement Input	$ 506,000,000		$ 506,000,000		$ 389,000,000
Decommissioning Trust Funds [Abstract]
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax							$ (6,806,000)	$ (632,617,000)
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts	1,303,000	$ (825,000)	17,472,000	$ 1,708,000
Amortized cost of debt securities	$ 2,362,000,000		$ 2,362,000,000		2,511,000,000
Average coupon rate of debt securities	3.15%		3.15%
Average duration of debt securities, years			5 years 7 months 17 days
Average maturity of debt securities, years			9 years 7 days
Proceeds from the dispositions of debt securities	$ 407,000,000	2,377,000,000	$ 1,133,000,000	4,178,000,000
Gains from dispositions of debt securities, gross	11,000,000	4,000,000	20,000,000	6,000,000
Losses from dispositions of debt securities, gross	400,000	15,000,000	3,000,000	37,000,000
Equity Securities, FV-NI, Unrealized Gain	17,000,000		491,000,000
Debt Securities [Member]
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts			16,000,000		(1,000,000)
Entergy Arkansas [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 396,800,000		$ 396,800,000		389,000,000
Average coupon rate of debt securities	2.78%		2.78%
Average duration of debt securities, years			5 years 6 months 25 days
Average maturity of debt securities, years			8 years 1 month 17 days
Proceeds from the dispositions of debt securities	$ 45,500,000	137,900,000	$ 78,700,000	259,300,000
Gains from dispositions of debt securities, gross	2,000,000	10,000	2,100,000	100,000
Losses from dispositions of debt securities, gross		600,000	100,000	3,000,000
Equity Securities, FV-NI, Unrealized Gain	2,600,000		96,500,000
Entergy Louisiana [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 561,000,000		$ 561,000,000		534,800,000
Average coupon rate of debt securities	3.85%		3.85%
Average duration of debt securities, years			6 years 6 months 10 days
Average maturity of debt securities, years			13 years 1 month 9 days
Proceeds from the dispositions of debt securities	$ 59,700,000	773,900,000	$ 155,400,000	943,300,000
Gains from dispositions of debt securities, gross	2,500,000	1,900,000	4,200,000	2,500,000
Losses from dispositions of debt securities, gross	29,000	3,600,000	$ 200,000	4,800,000
Percentage Interest in River Bend			30.00%
Equity Securities, FV-NI, Unrealized Gain	6,000,000		$ 137,200,000
System Energy [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 375,600,000		$ 375,600,000		367,100,000
Average coupon rate of debt securities	3.09%		3.09%
Average duration of debt securities, years			6 years 10 months 2 days
Average maturity of debt securities, years			9 years 10 months 17 days
Proceeds from the dispositions of debt securities	$ 108,600,000	157,800,000	$ 238,400,000	357,200,000
Gains from dispositions of debt securities, gross	1,700,000	6,500	3,600,000	300,000
Losses from dispositions of debt securities, gross	200,000	$ 300,000	600,000	$ 4,800,000
Equity Securities, FV-NI, Unrealized Gain	2,500,000		91,800,000
Indian Point 3 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	893,000,000		893,000,000		781,000,000
Indian Point 1 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	534,000,000		534,000,000		471,000,000
Indian Point 2 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	676,000,000		676,000,000		598,000,000
Palisades [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	$ 492,000,000		$ 492,000,000		444,000,000
Pilgrim [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value					1,028,000,000	$ 1,030,000,000
Vermont Yankee [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value					$ 532,000,000
Entergy Nuclear Generation Company [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value						$ 1,030,000,000

Decommissioning Trust Funds (Se

Decommissioning Trust Funds (Securities Held) (Details) - Debt Securities [Member] - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Fair Value	$ 2,462	$ 2,495
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	114	19
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	2	35
Entergy Arkansas [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	407.7	381.3
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	11.8	0.6
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.9	8.2
Entergy Louisiana [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	593.4	532.9
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	32.6	4.1
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.3	6
System Energy [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	395.3	364.2
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	19.7	2.9
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	$ 0.1	$ 5.8

Decommissioning Trust Funds (Av

Decommissioning Trust Funds (Available For Sale Securities Continuous Unrealized Loss Position Fair Value) (Details) - Debt Securities [Member] - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	$ 236	$ 652
More than 12 months Fair Value	67	782
Total Fair Value	303	1,434
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	2	9
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0	26
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	2	35
Entergy Arkansas [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	51.5	65.8
More than 12 months Fair Value	21	231.1
Total Fair Value	72.5	296.9
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0.8	0.5
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.1	7.7
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	0.9	8.2
Entergy Louisiana [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	49.3	170.1
More than 12 months Fair Value	12.9	145.8
Total Fair Value	62.2	315.9
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0.3	2.1
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0	3.9
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	0.3	6
System Energy [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	38.8	89.7
More than 12 months Fair Value	4.3	79.8
Total Fair Value	43.1	169.5
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0.1	2.4
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0	3.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	$ 0.1	$ 5.8

Decommissioning Trust Funds (Fa

Decommissioning Trust Funds (Fair Value Of Debt Securities By Contractual Maturities) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Fair value of debt securities by contractual maturities
Less than 1 year	$ 165	$ 199
1 year - 5 years	870	1,066
5 years - 10 years	636	544
10 years - 15 years	89	77
15 years - 20 years	98	78
20 years+	604	531
Total	2,462	2,495
Entergy Arkansas [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	50.3	32.5
1 year - 5 years	120.4	170.3
5 years - 10 years	144.5	114
10 years - 15 years	24.3	10.3
15 years - 20 years	14.2	8.1
20 years+	54	46.1
Total	407.7	381.3
Entergy Louisiana [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	56.6	31.1
1 year - 5 years	138.2	130.5
5 years - 10 years	118.4	111
10 years - 15 years	34.7	29
15 years - 20 years	45	37.1
20 years+	200.5	194.2
Total	593.4	532.9
System Energy [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	11.2	22.8
1 year - 5 years	187.7	188
5 years - 10 years	92.7	73.4
10 years - 15 years	3	5.2
15 years - 20 years	5.9	10.2
20 years+	94.8	64.6
Total	$ 395.3	$ 364.2

Income Taxes Income Taxes (Narr

Income Taxes Income Taxes (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	3 Months Ended	9 Months Ended	12 Months Ended
	Sep. 30, 2019	Mar. 31, 2019	Sep. 30, 2019	Dec. 31, 2022	Dec. 31, 2021	Oct. 15, 2024
Discontinued Operation, Tax Effect of Discontinued Operation		$ 29
Entergy Arkansas [Member]
State Effective Income Tax Rate, Percent			6.50%
Regulatory Liability For Income Taxes - Current and Non Current	$ 25		$ 25
Entergy Arkansas [Member] | Subsequent Event [Member]
State Effective Income Tax Rate, Percent				5.90%	6.20%
Reduction to Effective Income Tax Rate At Combined Federal and State Income Tax Rate				0.50%
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Entergy Texas [Member]
Preferred Stock, Dividend Rate, Percentage	5.375%		5.375%
Preferred Stock, Liquidation Preference Per Share	$ 25		$ 25
Proceeds from Issuance of Preferred Stock and Preference Stock	$ 35		$ 35
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Entergy Texas [Member] | Subsequent Event [Member]
Preferred Stock, Liquidation Preference Per Share						$ 25

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		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	$ 96	$ 283	$ 219	$ 562
Entergy Arkansas [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	41	153	99	260
Entergy Louisiana [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	17	55	31	86
Entergy Mississippi [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	0	32	0	161
Entergy New Orleans [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	7	9	9	9
Entergy Texas [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	31	0	73	0
System Energy [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	$ 0	$ 34	$ 7	$ 46

Property, Plant, And Equipment

Property, Plant, And Equipment (Narrative) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Construction expenditures in accounts payable	$ 306	$ 311
Entergy Arkansas [Member]
Construction expenditures in accounts payable	41.7	35.7
Entergy Louisiana [Member]
Construction expenditures in accounts payable	74	104.6
Entergy Mississippi [Member]
Construction expenditures in accounts payable	14.7	13.6
Entergy New Orleans [Member]
Construction expenditures in accounts payable	13.9	5.8
Entergy Texas [Member]
Construction expenditures in accounts payable	81.6	55.6
System Energy [Member]
Construction expenditures in accounts payable	$ 24.6	$ 26.3

Variable Interest Entities (Nar

Variable Interest Entities (Narrative) (Details) - Grand Gulf [Member] - System Energy [Member] - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Variable Interest Entity [Line Items]
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage		11.50%
Payments on lease, including interest	$ 8.6	$ 17.2	$ 17.2

Revenue Recognition (Disaggrega

Revenue Recognition (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Revenue from Contract with Customer, Excluding Assessed Tax	$ 3,140,575	$ 3,104,319	$ 8,416,367	$ 8,496,970
Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,812,934	2,697,887	7,279,683	7,276,374
Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	27,269	26,352	112,916	112,990
Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	300,372	380,080	1,023,768	1,107,606
Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,154,455	1,138,744	2,727,367	2,799,539
Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	722,334	693,760	1,871,416	1,871,380
Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	686,122	682,823	1,928,857	1,904,828
Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	61,697	60,647	172,280	173,949
Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	63,082	76,247	222,834	214,984
Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	115,352	42,847	326,771	289,668
Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	9,892	2,819	30,158	22,026
Non-Customer [Member] | Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	17,952	(27,683)	100,480	(40,854)
Competitive Business Sales [Member] | Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	282,420	407,763	923,288	1,148,460
Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,624,608	2,575,974	6,699,920	6,749,696
Entergy Arkansas [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	687,526	568,399	1,776,267	1,614,028
Entergy Arkansas [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	687,526	568,399	1,776,267	1,614,028
Entergy Arkansas [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Entergy Arkansas [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	253,627	250,081	621,208	644,735
Entergy Arkansas [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	162,564	119,950	412,697	334,325
Entergy Arkansas [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	156,024	126,079	396,515	335,529
Entergy Arkansas [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	5,907	4,445	15,776	12,859
Entergy Arkansas [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	58,953	60,338	213,038	179,637
Entergy Arkansas [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	47,085	4,446	107,599	98,571
Entergy Arkansas [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	3,366	3,060	9,434	8,372
Entergy Arkansas [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	578,122	500,555	1,446,196	1,327,448
Entergy Louisiana [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,231,677	1,206,612	3,297,324	3,308,744
Entergy Louisiana [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,221,874	1,196,278	3,252,826	3,263,073
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	9,803	10,334	44,498	45,671
Entergy Louisiana [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	426,012	408,680	980,443	972,113
Entergy Louisiana [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	277,071	272,985	715,983	719,652
Entergy Louisiana [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	376,595	393,884	1,108,193	1,114,898
Entergy Louisiana [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	18,731	17,566	53,547	51,581
Entergy Louisiana [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	81,664	71,634	248,827	272,690
Entergy Louisiana [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	37,521	34,220	130,269	124,749
Entergy Louisiana [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	4,280	(2,691)	15,564	7,390
Entergy Louisiana [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,098,409	1,093,115	2,858,166	2,858,244
Entergy Mississippi [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	398,732	367,734	983,713	1,037,166
Entergy Mississippi [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	398,732	367,734	983,713	1,037,166
Entergy Mississippi [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Entergy Mississippi [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	177,785	170,258	423,395	451,331
Entergy Mississippi [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	131,596	126,987	331,785	354,799
Entergy Mississippi [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	44,054	44,383	120,490	133,012
Entergy Mississippi [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	12,551	11,488	33,108	33,788
Entergy Mississippi [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	9,569	7,876	19,377	21,645
Entergy Mississippi [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	20,499	4,079	47,887	35,055
Entergy Mississippi [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,678	2,663	7,671	7,536
Entergy Mississippi [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	365,986	353,116	908,778	972,930
Entergy New Orleans [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	194,204	200,182	533,191	566,903
Entergy New Orleans [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	176,738	184,164	464,773	499,584
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	17,466	16,018	68,418	67,319
Entergy New Orleans [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	81,468	86,014	192,165	208,821
Entergy New Orleans [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	56,430	62,428	156,152	171,224
Entergy New Orleans [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	8,613	9,655	24,353	26,493
Entergy New Orleans [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	19,030	20,364	53,916	56,503
Entergy New Orleans [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	6,876	4,863	25,680	24,390
Entergy New Orleans [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,537	(1,107)	8,093	7,404
Entergy New Orleans [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,784	1,947	4,414	4,749
Entergy New Orleans [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	165,541	178,461	426,586	463,041
Entergy Texas [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	442,877	477,231	1,146,931	1,229,657
Entergy Texas [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	442,877	477,231	1,146,931	1,229,657
Entergy Texas [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Entergy Texas [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	215,563	223,711	510,156	522,539
Entergy Texas [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	94,673	111,409	254,799	291,380
Entergy Texas [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	100,836	108,823	279,306	294,896
Entergy Texas [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	5,478	6,785	15,933	19,218
Entergy Texas [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	16,704	23,290	48,251	71,828
Entergy Texas [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	9,177	2,735	37,329	28,468
Entergy Texas [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	446	478	1,157	1,328
Entergy Texas [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	416,550	450,728	1,060,194	1,128,033
System Energy [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 145,472	$ 78,965	$ 424,585	$ 339,864

Asset Retirement Obligations _2

Asset Retirement Obligations Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Mar. 31, 2019
Entergy Louisiana [Member]
Increase in decommissioning liability	$ 147.5
Entergy Arkansas [Member]
Increase in decommissioning liability		$ 126.2

Leases Leases (Narrative) (Deta

Leases Leases (Narrative) (Details) - USD ($)	1 Months Ended	3 Months Ended	9 Months Ended	12 Months Ended
	Mar. 31, 2016	Sep. 30, 2019	Sep. 30, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jan. 31, 2019	Dec. 31, 2015	Dec. 31, 1989	Dec. 31, 1988
Short-term Lease, Cost		$ 15,000	$ 15,000
Operating Lease, Right-of-Use Asset		236,000,000	236,000,000
Operating and Finance Lease Right of Use Asset and Lease Liabilities at Implementation							$ 263,000,000
Operating Leases, Rent Expense, Net				$ 47,800,000	$ 53,100,000	$ 44,400,000
Finance Lease, Right-of-Use Asset		60,000,000	60,000,000
Entergy Arkansas [Member]
Operating Lease, Right-of-Use Asset		49,503,000	49,503,000
Operating and Finance Lease Right of Use Asset and Lease Liabilities at Implementation							59,000,000
Operating Leases, Rent Expense, Net				6,200,000	7,500,000	8,000,000
Payments For Railcar Operating Lease				2,800,000	4,000,000	3,400,000
Finance Lease, Right-of-Use Asset		11,094,000	11,094,000
Entergy Louisiana [Member]
Short-term Lease, Cost		15,000	15,000
Operating Lease, Right-of-Use Asset		34,248,000	34,248,000
Operating and Finance Lease Right of Use Asset and Lease Liabilities at Implementation							51,000,000
Operating Leases, Rent Expense, Net				$ 20,200,000	23,000,000	17,800,000
Percentage Of Capacity And Energy Purchased Under Purchased Power Agreement				50.00%
Cash payment representing the purchase price to acquire the undivided interests in Waterford 3	$ 60,000,000
Portion of Waterford 3 purchase price satisfied through issuance of debt	$ 52,000,000
Payments For Railcar Operating Lease				$ 400,000	300,000	300,000
Finance Lease, Right-of-Use Asset		16,795,000	16,795,000
Entergy Mississippi [Member]
Operating Lease, Right-of-Use Asset		18,149,000	18,149,000
Operating and Finance Lease Right of Use Asset and Lease Liabilities at Implementation							26,000,000
Operating Leases, Rent Expense, Net				4,600,000	5,600,000	4,000,000
Oil Tank Facilities Lease Payments				100,000	1,600,000	1,600,000
Finance Lease, Right-of-Use Asset		6,994,000	6,994,000
Entergy New Orleans [Member]
Operating Lease, Right-of-Use Asset		3,894,000	3,894,000
Operating and Finance Lease Right of Use Asset and Lease Liabilities at Implementation							7,000,000
Operating Leases, Rent Expense, Net				2,500,000	2,500,000	900,000
Finance Lease, Right-of-Use Asset		2,913,000	2,913,000
Entergy Texas [Member]
Operating Lease, Right-of-Use Asset		13,074,000	13,074,000
Operating and Finance Lease Right of Use Asset and Lease Liabilities at Implementation							$ 16,000,000
Operating Leases, Rent Expense, Net				$ 3,100,000	3,400,000	2,800,000
Percent of minimum payments				100.00%
Capacity expense under purchase power agreements accounted for as operating leases				$ 30,500,000	34,100,000	26,100,000
Finance Lease, Right-of-Use Asset		$ 5,515,000	$ 5,515,000
System Energy [Member]
Operating Leases, Rent Expense, Net				1,900,000	2,200,000	$ 1,600,000
Grand Gulf [Member] | System Energy [Member]
Sale Leaseback Transaction, Net Book Value										$ 500,000,000
Regulatory Assets				0
Regulatory Liabilities				$ 55,600,000	$ 55,600,000
Waterford Three [Member] | Entergy Louisiana [Member]
Liability related to undivided interests in Waterford 3								$ 62,700,000
Reduced liability related to undivided interests in Waterford 3								60,000,000
Reduction in liability related to undivided interest in Waterford 3 recorded as credit to interest expense								$ 2,700,000
Implicit Rate Of Future Minimum Lease Payments						8.09%
Minimum Lease Payments, Sale Leaseback Transactions						$ 57,500,000
Interest Portion of Minimum Lease Payments, Sale Leaseback Transactions						$ 2,300,000
Sale Leaseback Transaction, Net Book Value									$ 353,600,000

Leases Leases (Lease, Cost) (De

Leases Leases (Lease, Cost) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
Short-term Lease, Cost	$ 15	$ 15
Operating Lease, Expense	16,086	47,061
Finance Lease, Right-of-Use Asset, Amortization	2,945	10,837
Finance Lease, Interest Expense	763	2,597
Entergy Arkansas [Member]
Operating Lease, Expense	3,306	9,724
Finance Lease, Right-of-Use Asset, Amortization	621	2,448
Finance Lease, Interest Expense	105	408
Entergy Louisiana [Member]
Short-term Lease, Cost	15	15
Operating Lease, Expense	3,003	8,854
Finance Lease, Right-of-Use Asset, Amortization	1,014	4,014
Finance Lease, Interest Expense	161	612
Entergy Mississippi [Member]
Operating Lease, Expense	1,752	5,220
Finance Lease, Right-of-Use Asset, Amortization	369	1,408
Finance Lease, Interest Expense	65	241
Entergy New Orleans [Member]
Operating Lease, Expense	349	1,058
Finance Lease, Right-of-Use Asset, Amortization	178	696
Finance Lease, Interest Expense	29	114
Entergy Texas [Member]
Operating Lease, Expense	1,074	3,135
Finance Lease, Right-of-Use Asset, Amortization	335	965
Finance Lease, Interest Expense	$ 54	$ 153

Leases Leases (Lease, Assets) (

Leases Leases (Lease, Assets) (Details) $ in Thousands	Sep. 30, 2019USD ($)
Operating Lease, Right-of-Use Asset	$ 236,000
Finance Lease, Right-of-Use Asset	60,000
Entergy Arkansas [Member]
Operating Lease, Right-of-Use Asset	49,503
Finance Lease, Right-of-Use Asset	11,094
Entergy Louisiana [Member]
Operating Lease, Right-of-Use Asset	34,248
Finance Lease, Right-of-Use Asset	16,795
Entergy Mississippi [Member]
Operating Lease, Right-of-Use Asset	18,149
Finance Lease, Right-of-Use Asset	6,994
Entergy New Orleans [Member]
Operating Lease, Right-of-Use Asset	3,894
Finance Lease, Right-of-Use Asset	2,913
Entergy Texas [Member]
Operating Lease, Right-of-Use Asset	13,074
Finance Lease, Right-of-Use Asset	$ 5,515

Leases Leases (Lease, Liabiliti

Leases Leases (Lease, Liabilities) (Details) $ in Thousands	Sep. 30, 2019USD ($)
Operating Lease, Liability, Current	$ 52,348
Finance Lease, Liability, Current	11,482
Operating Lease, Liability, Noncurrent	184,404
Finance Lease, Liability, Noncurrent	53,252
Entergy Arkansas [Member]
Operating Lease, Liability, Current	10,662
Finance Lease, Liability, Current	2,600
Operating Lease, Liability, Noncurrent	38,881
Finance Lease, Liability, Noncurrent	8,665
Entergy Louisiana [Member]
Operating Lease, Liability, Current	9,969
Finance Lease, Liability, Current	3,860
Operating Lease, Liability, Noncurrent	24,289
Finance Lease, Liability, Noncurrent	12,925
Entergy Mississippi [Member]
Operating Lease, Liability, Current	6,137
Finance Lease, Liability, Current	1,473
Operating Lease, Liability, Noncurrent	12,254
Finance Lease, Liability, Noncurrent	5,521
Entergy New Orleans [Member]
Operating Lease, Liability, Current	1,138
Finance Lease, Liability, Current	626
Operating Lease, Liability, Noncurrent	2,755
Finance Lease, Liability, Noncurrent	2,286
Entergy Texas [Member]
Operating Lease, Liability, Current	3,427
Finance Lease, Liability, Current	1,252
Operating Lease, Liability, Noncurrent	9,689
Finance Lease, Liability, Noncurrent	$ 4,221

Leases Leases (Lease, Terms and

Leases Leases (Lease, Terms and Discount Rate) (Details)	Sep. 30, 2019
Operating Lease, Weighted Average Remaining Lease Term	5 years 1 month 6 days
Finance Lease, Weighted Average Remaining Lease Term	6 years 9 months 14 days
Operating Lease, Weighted Average Discount Rate, Percent	3.91%
Finance Lease, Weighted Average Discount Rate, Percent	4.67%
Entergy Arkansas [Member]
Operating Lease, Weighted Average Remaining Lease Term	6 years 1 month 2 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 5 months 8 days
Operating Lease, Weighted Average Discount Rate, Percent	3.75%
Finance Lease, Weighted Average Discount Rate, Percent	3.75%
Entergy Louisiana [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 3 months 10 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 4 months 28 days
Operating Lease, Weighted Average Discount Rate, Percent	3.74%
Finance Lease, Weighted Average Discount Rate, Percent	3.75%
Entergy Mississippi [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 7 months 24 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 4 months 28 days
Operating Lease, Weighted Average Discount Rate, Percent	3.77%
Finance Lease, Weighted Average Discount Rate, Percent	3.71%
Entergy New Orleans [Member]
Operating Lease, Weighted Average Remaining Lease Term	3 years 11 months 26 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 8 months 19 days
Operating Lease, Weighted Average Discount Rate, Percent	3.94%
Finance Lease, Weighted Average Discount Rate, Percent	3.93%
Entergy Texas [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 5 months 26 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 3 months
Operating Lease, Weighted Average Discount Rate, Percent	3.86%
Finance Lease, Weighted Average Discount Rate, Percent	3.84%

Leases Leases (Lease, Maturity)

Leases Leases (Lease, Maturity) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Operating Lease, Weighted Average Remaining Lease Term	5 years 1 month 6 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 16,088
Finance Lease, Liability, Payments, Remainder of Fiscal Year	3,608
Lessee, Operating Lease, Liability, Payments, Due Year Two	59,965	$ 31,876
Finance Lease, Liability, Payments, Due Year Two	13,521
Lessee, Operating Lease, Liability, Payments, Due Year Three	53,791	32,609
Finance Lease, Liability, Payments, Due Year Three	11,973
Lessee, Operating Lease, Liability, Payments, Due Year Four	45,391	10,180
Finance Lease, Liability, Payments, Due Year Four	10,775
Lessee, Operating Lease, Liability, Payments, Due Year Five	35,050
Finance Lease, Liability, Payments, Due Year Five	9,664
Lessee, Operating Lease, Liability, Payments, Due after Year Five	56,906
Finance Lease, Liability, Payments, Due after Year Five	26,889
Lessee, Operating Lease, Liability, Payments, Due	267,191	105,824
Operating Lease, Cost	30,438
Finance Lease, Liability, Payments, Due	76,430
Finance Lease, Interest Payment on Liability	11,696
Present Value Net Minimum Operating Lease Payments	236,753
Present Value Net Minimum Financing Lease Payments	$ 64,734
Finance Lease, Weighted Average Remaining Lease Term	6 years 9 months 14 days
Operating Lease, Weighted Average Discount Rate, Percent	3.91%
Finance Lease, Weighted Average Discount Rate, Percent	4.67%
Entergy Arkansas [Member]
Operating Lease, Weighted Average Remaining Lease Term	6 years 1 month 2 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 3,168
Finance Lease, Liability, Payments, Remainder of Fiscal Year	713
Lessee, Operating Lease, Liability, Payments, Due Year Two	11,756
Finance Lease, Liability, Payments, Due Year Two	2,654
Lessee, Operating Lease, Liability, Payments, Due Year Three	9,911
Finance Lease, Liability, Payments, Due Year Three	2,258
Lessee, Operating Lease, Liability, Payments, Due Year Four	7,613
Finance Lease, Liability, Payments, Due Year Four	1,969
Lessee, Operating Lease, Liability, Payments, Due Year Five	6,341
Finance Lease, Liability, Payments, Due Year Five	1,728
Lessee, Operating Lease, Liability, Payments, Due after Year Five	16,421
Finance Lease, Liability, Payments, Due after Year Five	2,905
Lessee, Operating Lease, Liability, Payments, Due	55,210
Operating Lease, Cost	5,667
Finance Lease, Liability, Payments, Due	12,227
Finance Lease, Interest Payment on Liability	961
Present Value Net Minimum Operating Lease Payments	49,543
Present Value Net Minimum Financing Lease Payments	$ 11,266
Finance Lease, Weighted Average Remaining Lease Term	5 years 5 months 8 days
Operating Lease, Weighted Average Discount Rate, Percent	3.75%
Finance Lease, Weighted Average Discount Rate, Percent	3.75%
Entergy Louisiana [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 3 months 10 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 2,863
Finance Lease, Liability, Payments, Remainder of Fiscal Year	1,135
Lessee, Operating Lease, Liability, Payments, Due Year Two	10,518
Finance Lease, Liability, Payments, Due Year Two	4,191
Lessee, Operating Lease, Liability, Payments, Due Year Three	8,787
Finance Lease, Liability, Payments, Due Year Three	3,536
Lessee, Operating Lease, Liability, Payments, Due Year Four	6,068
Finance Lease, Liability, Payments, Due Year Four	3,096
Lessee, Operating Lease, Liability, Payments, Due Year Five	4,079
Finance Lease, Liability, Payments, Due Year Five	2,635
Lessee, Operating Lease, Liability, Payments, Due after Year Five	4,702
Finance Lease, Liability, Payments, Due after Year Five	3,818
Lessee, Operating Lease, Liability, Payments, Due	37,017
Operating Lease, Cost	2,759
Finance Lease, Liability, Payments, Due	18,411
Finance Lease, Interest Payment on Liability	1,626
Present Value Net Minimum Operating Lease Payments	34,258
Present Value Net Minimum Financing Lease Payments	$ 16,785
Finance Lease, Weighted Average Remaining Lease Term	5 years 4 months 28 days
Operating Lease, Weighted Average Discount Rate, Percent	3.74%
Finance Lease, Weighted Average Discount Rate, Percent	3.75%
Entergy Mississippi [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 7 months 24 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 1,968
Finance Lease, Liability, Payments, Remainder of Fiscal Year	429
Lessee, Operating Lease, Liability, Payments, Due Year Two	6,066
Finance Lease, Liability, Payments, Due Year Two	1,655
Lessee, Operating Lease, Liability, Payments, Due Year Three	4,937
Finance Lease, Liability, Payments, Due Year Three	1,490
Lessee, Operating Lease, Liability, Payments, Due Year Four	3,503
Finance Lease, Liability, Payments, Due Year Four	1,297
Lessee, Operating Lease, Liability, Payments, Due Year Five	1,376
Finance Lease, Liability, Payments, Due Year Five	1,078
Lessee, Operating Lease, Liability, Payments, Due after Year Five	2,642
Finance Lease, Liability, Payments, Due after Year Five	1,740
Lessee, Operating Lease, Liability, Payments, Due	20,492
Operating Lease, Cost	2,101
Finance Lease, Liability, Payments, Due	7,689
Finance Lease, Interest Payment on Liability	695
Present Value Net Minimum Operating Lease Payments	18,391
Present Value Net Minimum Financing Lease Payments	$ 6,994
Finance Lease, Weighted Average Remaining Lease Term	5 years 4 months 28 days
Operating Lease, Weighted Average Discount Rate, Percent	3.77%
Finance Lease, Weighted Average Discount Rate, Percent	3.71%
Entergy New Orleans [Member]
Operating Lease, Weighted Average Remaining Lease Term	3 years 11 months 26 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 332
Finance Lease, Liability, Payments, Remainder of Fiscal Year	204
Lessee, Operating Lease, Liability, Payments, Due Year Two	1,196
Finance Lease, Liability, Payments, Due Year Two	660
Lessee, Operating Lease, Liability, Payments, Due Year Three	939
Finance Lease, Liability, Payments, Due Year Three	549
Lessee, Operating Lease, Liability, Payments, Due Year Four	659
Finance Lease, Liability, Payments, Due Year Four	499
Lessee, Operating Lease, Liability, Payments, Due Year Five	497
Finance Lease, Liability, Payments, Due Year Five	451
Lessee, Operating Lease, Liability, Payments, Due after Year Five	729
Finance Lease, Liability, Payments, Due after Year Five	881
Lessee, Operating Lease, Liability, Payments, Due	4,352
Operating Lease, Cost	459
Finance Lease, Liability, Payments, Due	3,244
Finance Lease, Interest Payment on Liability	332
Present Value Net Minimum Operating Lease Payments	3,893
Present Value Net Minimum Financing Lease Payments	$ 2,912
Finance Lease, Weighted Average Remaining Lease Term	5 years 8 months 19 days
Operating Lease, Weighted Average Discount Rate, Percent	3.94%
Finance Lease, Weighted Average Discount Rate, Percent	3.93%
Entergy Texas [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 5 months 26 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 1,022
Finance Lease, Liability, Payments, Remainder of Fiscal Year	375
Lessee, Operating Lease, Liability, Payments, Due Year Two	4,014	31,876
Finance Lease, Liability, Payments, Due Year Two	1,364
Lessee, Operating Lease, Liability, Payments, Due Year Three	3,279	32,609
Finance Lease, Liability, Payments, Due Year Three	1,171
Lessee, Operating Lease, Liability, Payments, Due Year Four	2,338	10,180
Finance Lease, Liability, Payments, Due Year Four	965
Lessee, Operating Lease, Liability, Payments, Due Year Five	1,994
Finance Lease, Liability, Payments, Due Year Five	827
Lessee, Operating Lease, Liability, Payments, Due after Year Five	2,193
Finance Lease, Liability, Payments, Due after Year Five	1,316
Lessee, Operating Lease, Liability, Payments, Due	14,840	$ 105,824
Operating Lease, Cost	1,724
Finance Lease, Liability, Payments, Due	6,018
Finance Lease, Interest Payment on Liability	545
Present Value Net Minimum Operating Lease Payments	13,116
Present Value Net Minimum Financing Lease Payments	$ 5,473
Finance Lease, Weighted Average Remaining Lease Term	5 years 3 months
Operating Lease, Weighted Average Discount Rate, Percent	3.86%
Finance Lease, Weighted Average Discount Rate, Percent	3.84%

Leases Leases (Operating And Ca

Leases Leases (Operating And Capital Leases Future Minimum Payments Due) (Details) $ in Thousands	Dec. 31, 2018USD ($)
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$ 94,043
Capital Leases, Future Minimum Payments Due, Next Twelve Months	2,887
Operating Leases, Future Minimum Payments, Due in Two Years	82,191
Capital Leases, Future Minimum Payments Due in Two Years	2,887
Operating Leases, Future Minimum Payments, Due in Three Years	75,147
Capital Leases, Future Minimum Payments Due in Three Years	2,887
Operating Leases, Future Minimum Payments, Due in Four Years	60,808
Capital Leases, Future Minimum Payments Due in Four Years	2,887
Operating Leases, Future Minimum Payments, Due in Five Years	47,391
Capital Leases, Future Minimum Payments Due in Five Years	2,887
Operating Leases, Future Minimum Payments, Due Thereafter	88,004
Capital Leases, Future Minimum Payments Due Thereafter	16,117
Operating Leases, Future Minimum Payments Due	447,584
Capital Leases, Future Minimum Payments Due	30,552
Capital Leases, Future Minimum Payments, Interest Included in Payments	8,555
Capital Leases, Future Minimum Payments, Present Value of Net Minimum Payments	21,997
Entergy Arkansas [Member]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	20,421
Operating Leases, Future Minimum Payments, Due in Two Years	13,918
Operating Leases, Future Minimum Payments, Due in Three Years	11,931
Operating Leases, Future Minimum Payments, Due in Four Years	9,458
Operating Leases, Future Minimum Payments, Due in Five Years	7,782
Operating Leases, Future Minimum Payments, Due Thereafter	23,297
Operating Leases, Future Minimum Payments Due	86,807
Entergy Louisiana [Member]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	25,970
Operating Leases, Future Minimum Payments, Due in Two Years	21,681
Operating Leases, Future Minimum Payments, Due in Three Years	19,514
Operating Leases, Future Minimum Payments, Due in Four Years	15,756
Operating Leases, Future Minimum Payments, Due in Five Years	12,092
Operating Leases, Future Minimum Payments, Due Thereafter	22,003
Operating Leases, Future Minimum Payments Due	117,016
Entergy Mississippi [Member]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	9,344
Operating Leases, Future Minimum Payments, Due in Two Years	8,763
Operating Leases, Future Minimum Payments, Due in Three Years	7,186
Operating Leases, Future Minimum Payments, Due in Four Years	5,675
Operating Leases, Future Minimum Payments, Due in Five Years	2,946
Operating Leases, Future Minimum Payments, Due Thereafter	4,417
Operating Leases, Future Minimum Payments Due	38,331
Entergy New Orleans [Member]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	2,493
Operating Leases, Future Minimum Payments, Due in Two Years	2,349
Operating Leases, Future Minimum Payments, Due in Three Years	1,901
Operating Leases, Future Minimum Payments, Due in Four Years	1,314
Operating Leases, Future Minimum Payments, Due in Five Years	1,043
Operating Leases, Future Minimum Payments, Due Thereafter	2,323
Operating Leases, Future Minimum Payments Due	11,423
Entergy Texas [Member]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	5,744
Operating Leases, Future Minimum Payments, Due in Two Years	4,431
Operating Leases, Future Minimum Payments, Due in Three Years	3,625
Operating Leases, Future Minimum Payments, Due in Four Years	2,218
Operating Leases, Future Minimum Payments, Due in Five Years	1,561
Operating Leases, Future Minimum Payments, Due Thereafter	2,726
Operating Leases, Future Minimum Payments Due	$ 20,305

Leases Leases (Schedule of Rent

Leases Leases (Schedule of Rent Expense) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating Leases, Rent Expense, Net	$ 47.8	$ 53.1	$ 44.4
Entergy Arkansas [Member]
Operating Leases, Rent Expense, Net	6.2	7.5	8
Entergy Louisiana [Member]
Operating Leases, Rent Expense, Net	20.2	23	17.8
Entergy Mississippi [Member]
Operating Leases, Rent Expense, Net	4.6	5.6	4
Entergy New Orleans [Member]
Operating Leases, Rent Expense, Net	2.5	2.5	0.9
Entergy Texas [Member]
Operating Leases, Rent Expense, Net	3.1	3.4	2.8
System Energy [Member]
Operating Leases, Rent Expense, Net	$ 1.9	$ 2.2	$ 1.6

Leases Leases (Purchase Power A

Leases Leases (Purchase Power Agreement Minimum Lease Payments) (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months		$ 31,159
Lessee, Operating Lease, Liability, Payments, Due Year Two	$ 59,965	31,876
Lessee, Operating Lease, Liability, Payments, Due Year Three	53,791	32,609
Lessee, Operating Lease, Liability, Payments, Due Year Four	45,391	10,180
Lessee, Operating Lease, Liability, Payments, Due	267,191	105,824
Entergy Texas [Member]
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months		31,159
Lessee, Operating Lease, Liability, Payments, Due Year Two	4,014	31,876
Lessee, Operating Lease, Liability, Payments, Due Year Three	3,279	32,609
Lessee, Operating Lease, Liability, Payments, Due Year Four	2,338	10,180
Lessee, Operating Lease, Liability, Payments, Due	14,840	$ 105,824
Entergy Louisiana [Member]
Lessee, Operating Lease, Liability, Payments, Due Year Two	10,518
Lessee, Operating Lease, Liability, Payments, Due Year Three	8,787
Lessee, Operating Lease, Liability, Payments, Due Year Four	6,068
Lessee, Operating Lease, Liability, Payments, Due	$ 37,017

Leases Leases (Present Value Of

Leases Leases (Present Value Of future Minimum Lease Payments Sale Leaseback Transactions) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Long-term Debt, Fair Value	$ 18,628,268		$ 18,628,268		$ 15,880,239
Interest Expense, Debt	201,412	$ 195,311	603,517	$ 570,548
Entergy Arkansas [Member]
Long-term Debt, Fair Value	3,621,073		3,621,073		3,002,627
Interest Expense, Debt	35,454	31,632	104,664	92,315
Entergy Louisiana [Member]
Long-term Debt, Fair Value	8,038,675		8,038,675		6,834,134
Interest Expense, Debt	78,350	73,084	230,684	216,762
Entergy Mississippi [Member]
Long-term Debt, Fair Value	1,586,199		1,586,199		1,276,452
Interest Expense, Debt	15,922	13,950	45,804	41,916
Entergy New Orleans [Member]
Long-term Debt, Fair Value	522,688		522,688		491,569
Interest Expense, Debt	6,046	5,388	18,001	15,936
Entergy Texas [Member]
Long-term Debt, Fair Value	2,128,842		2,128,842		1,528,828
Interest Expense, Debt	21,379	21,760	63,992	65,646
System Energy [Member]
Long-term Debt, Fair Value	554,374		554,374		596,123
Interest Expense, Debt	$ 8,546	$ 9,753	$ 26,467	$ 28,734
Grand Gulf [Member] | System Energy [Member]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months					17,188
Long-term Debt, Maturities, Repayments of Principal in Year Two					17,188
Long-term Debt, Maturities, Repayments of Principal in Year Three					17,188
Long-term Debt, Maturities, Repayments of Principal in Year Four					17,188
Long-term Debt, Maturities, Repayments of Principal in Year Five					17,188
Long-term Debt, Maturities, Repayments of Principal after Year Five					223,437
Long-term Debt, Fair Value					309,377
Interest Expense, Debt					275,025
Long-term Debt					$ 34,352

Dispositions Dispositions (Narr

Dispositions Dispositions (Narrative) (Details) - USD ($)	1 Months Ended	3 Months Ended
	Aug. 31, 2019	Sep. 30, 2019	Mar. 31, 2019	Jan. 31, 2019	Dec. 31, 2018	Jul. 31, 2018
Business Acquisition [Line Items]
Amount Drawn/ Outstanding		$ 155,000,000
Discontinued Operation, Tax Effect of Discontinued Operation			$ 29,000,000
Restructuring Costs and Asset Impairment Charges			5,400,000
After-Tax Asset Impairment Charge			$ 4,200,000
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment		52,705,142,000			$ 49,831,486,000
Entergy Nuclear Vermont Yankee [Member]
Business Acquisition [Line Items]
Percentage of Undivided Ownership Interest				100.00%
Amount Drawn/ Outstanding		139,000,000		$ 139,000,000
Entergy Nuclear Generation Company [Member]
Business Acquisition [Line Items]
Percentage of Undivided Ownership Interest						100.00%
Proceeds from Divestiture of Businesses	$ 1,000
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property		191,000,000
Gain (Loss) on Sale of Properties, Net of Applicable Income Taxes		$ 156,000,000
Decommissioning Fund Investments, Fair Value	1,030,000,000
Asset Retirement Obligation	837,000,000
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment	$ 0

Uncategorized Items - etr-09x30

Label	Element	Value
Common Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	$ 2,616,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	2,548,000
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
Additional Paid-in Capital [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	5,951,431,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	5,433,433,000
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
Retained Earnings [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	8,727,956,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	8,553,959,000
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	576,257,000
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	6,806,000
AOCI Attributable to Parent [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(563,979,000)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(656,148,000)
Treasury Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(5,273,719,000)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(5,397,637,000)
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
Subsidiaries Preferred Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	$ 0