Entergy Texas (ETI-P) 10-Q 6 Aug 19 2019 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2019	Jul. 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	Jun. 30, 2019
Amendment Flag	false
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Incorporation, State or Country Code	DE
Entity Address, State or Province	639 Loyola Avenue
Entity Address, City or Town	New Orleans
Entity Address, State or Province	LA
Entity Address, Country	US
Entity Address, Postal Zip Code	70113
Entity Common Stock, Shares Outstanding		198,829,751
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]
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]
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]
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]
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]
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]
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]
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]
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]
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]
Trading Symbol	EAB
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.90% Series due December 2052

Consolidated Statements Of Inco

Consolidated Statements Of Income - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,666,209	$ 2,668,770	$ 5,275,792	$ 5,392,650
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	467,323	465,802	945,653	909,098
Nuclear refueling outage expenses	50,962	35,360	101,403	78,120
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	841,870	840,103	1,624,921	1,623,687
Asset Impairment Charges	16,419	68,943	90,397	141,867
Decommissioning	104,627	97,605	206,746	192,005
Taxes, Other	163,408	158,547	321,983	323,765
Other Depreciation and Amortization	363,496	350,485	720,770	697,471
Other regulatory charges (credits) - net	(26,532)	143,294	(43,478)	186,319
Costs and Expenses	2,327,434	2,577,173	4,653,763	4,965,390
OPERATING INCOME	338,775	91,597	622,029	427,260
OTHER INCOME
Allowance for equity funds used during construction	37,169	31,670	75,385	60,014
Investment Income, Net	96,218	71,134	324,367	88,005
Miscellaneous - net	(45,870)	(48,491)	(110,527)	(79,849)
TOTAL	87,517	54,313	289,225	68,170
INTEREST EXPENSE
Interest expense	201,112	192,314	402,105	375,237
Allowance for borrowed funds used during construction	(16,811)	(14,668)	(34,260)	(27,933)
TOTAL	184,301	177,646	367,845	347,304
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	241,991	(31,736)	543,409	148,126
Income taxes	1,458	(280,596)	44,229	(236,933)
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	4,109	3,439	8,219	6,878
Net Income (Loss) Available to Common Stockholders, Basic	$ 236,424	$ 245,421	$ 490,961	$ 378,181
Earnings per average common share:
Basic (in dollars per share)	$ 1.22	$ 1.36	$ 2.57	$ 2.09
Diluted (in dollars per share)	$ 1.22	$ 1.34	$ 2.54	$ 2.08
Basic average number of common shares outstanding (in shares)	193,019,269	180,823,203	191,306,742	180,765,708
Diluted average number of common shares outstanding (in shares)	194,238,315	182,982,630	193,243,287	182,208,328
Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,345,727	$ 2,330,225	$ 4,466,751	$ 4,578,486
Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	30,699	29,943	85,647	86,638
Competitive Businesses [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	289,783	308,602	723,394	727,526
Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	345,861	417,034	685,368	813,058
Entergy Arkansas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	542,929	494,605	1,088,741	1,045,629
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	108,596	106,496	260,755	214,802
Nuclear refueling outage expenses	17,194	19,159	34,442	42,561
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	188,006	177,792	354,466	347,150
Decommissioning	17,168	14,985	32,929	29,745
Taxes, Other	27,181	24,445	55,544	52,350
Other Depreciation and Amortization	77,061	72,701	152,908	144,682
Other regulatory charges (credits) - net	(10,336)	(12,313)	(9,891)	(15,620)
Costs and Expenses	473,155	468,104	976,496	952,481
OPERATING INCOME	69,774	26,501	112,245	93,148
OTHER INCOME
Allowance for equity funds used during construction	3,372	4,471	6,800	8,479
Investment Income, Net	4,222	2,478	10,405	9,292
Miscellaneous - net	(4,728)	(3,881)	(8,418)	(7,752)
TOTAL	2,866	3,068	8,787	10,019
INTEREST EXPENSE
Interest expense	35,827	30,917	69,210	60,683
Allowance for borrowed funds used during construction	(1,329)	(2,108)	(2,743)	(3,998)
TOTAL	34,498	28,809	66,467	56,685
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	38,142	760	54,565	46,482
Income taxes	(12,157)	(81,796)	(34,855)	(72,329)
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	0	357	0	714
Net Income (Loss) Available to Common Stockholders, Basic	50,299	82,199	89,420	118,097
Entergy Arkansas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	542,929	494,605	1,088,741	1,045,629
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	48,285	64,839	95,343	136,811
Entergy Louisiana [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,106,317	1,072,788	2,065,647	2,102,132
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	220,472	200,528	367,821	381,309
Nuclear refueling outage expenses	13,391	12,671	26,199	25,770
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	250,835	250,994	476,723	485,374
Decommissioning	14,059	13,480	27,938	26,252
Taxes, Other	46,658	47,147	96,340	98,427
Other Depreciation and Amortization	130,246	122,177	256,380	242,920
Other regulatory charges (credits) - net	(33,878)	9,017	(61,538)	32,214
Costs and Expenses	864,797	922,628	1,670,183	1,810,652
OPERATING INCOME	241,520	150,160	395,464	291,480
OTHER INCOME
Allowance for equity funds used during construction	20,671	19,124	44,585	36,869
Investment Income, Net	49,498	46,853	121,484	90,128
Miscellaneous - net	(22,306)	(22,770)	(64,650)	(30,435)
TOTAL	47,863	43,207	101,419	96,562
INTEREST EXPENSE
Interest expense	77,631	73,582	152,334	143,678
Allowance for borrowed funds used during construction	(9,737)	(9,451)	(21,104)	(18,214)
TOTAL	67,894	64,131	131,230	125,464
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	221,489	129,236	365,653	262,578
Income taxes	38,405	(55,122)	54,936	(33,374)
Net Income (Loss) Available to Common Stockholders, Basic	183,084	184,358	310,717	295,952
Entergy Louisiana [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,094,259	1,061,689	2,030,952	2,066,795
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	12,058	11,099	34,695	35,337
Entergy Louisiana [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	223,014	266,614	480,320	518,386
Entergy Mississippi [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	302,737	353,689	584,981	669,432
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	47,391	65,663	100,620	129,191
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	66,921	64,585	126,104	124,043
Taxes, Other	25,813	23,794	51,940	49,188
Other Depreciation and Amortization	39,718	38,359	78,806	76,541
Other regulatory charges (credits) - net	3,567	127,935	5,937	128,228
Costs and Expenses	257,130	417,490	508,582	691,801
OPERATING INCOME	45,607	(63,801)	76,399	(22,369)
OTHER INCOME
Allowance for equity funds used during construction	2,349	2,122	4,262	4,100
Investment Income, Net	397	0	549	25
Miscellaneous - net	(327)	(1,411)	(590)	(1,982)
TOTAL	2,419	711	4,221	2,143
INTEREST EXPENSE
Interest expense	15,342	14,061	29,882	27,966
Allowance for borrowed funds used during construction	(1,006)	(890)	(1,791)	(1,718)
TOTAL	14,336	13,171	28,091	26,248
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	33,690	(76,261)	52,529	(46,474)
Income taxes	7,023	(114,503)	10,464	(107,559)
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	0	239	0	477
Net Income (Loss) Available to Common Stockholders, Basic	26,667	38,003	42,065	60,608
Entergy Mississippi [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	302,737	353,689	584,981	669,432
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	73,720	97,154	145,175	184,610
Entergy New Orleans [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	175,793	178,446	338,987	366,721
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	27,190	15,366	57,950	39,105
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	32,252	28,420	62,550	56,719
Taxes, Other	13,135	12,851	26,677	27,983
Other Depreciation and Amortization	14,226	13,950	28,390	27,697
Other regulatory charges (credits) - net	4,500	6,127	2,145	12,460
Costs and Expenses	158,284	150,503	305,342	320,909
OPERATING INCOME	17,509	27,943	33,645	45,812
OTHER INCOME
Allowance for equity funds used during construction	2,686	1,217	4,976	2,068
Investment Income, Net	64	207	243	300
Miscellaneous - net	(942)	(1,404)	(2,448)	(1,741)
TOTAL	1,808	20	2,771	627
INTEREST EXPENSE
Interest expense	6,019	5,269	11,955	10,548
Allowance for borrowed funds used during construction	(1,073)	(450)	(1,987)	(764)
TOTAL	4,946	4,819	9,968	9,784
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	14,371	23,144	26,448	36,655
Income taxes	1,368	4,875	4,422	7,504
Entergy New Orleans [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	157,152	159,602	288,035	315,420
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	18,641	18,844	50,952	51,301
Entergy New Orleans [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	66,981	73,789	127,630	156,945
Entergy Texas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	363,580	403,486	704,054	752,426
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	16,971	57,089	65,074	75,795
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	61,426	59,848	121,052	112,522
Taxes, Other	21,263	20,306	39,903	40,709
Other Depreciation and Amortization	37,312	31,141	74,349	61,907
Other regulatory charges (credits) - net	19,453	25,897	38,912	51,514
Costs and Expenses	327,558	344,849	651,291	652,707
OPERATING INCOME	36,022	58,637	52,763	99,719
OTHER INCOME
Allowance for equity funds used during construction	6,413	1,833	11,494	3,494
Investment Income, Net	374	542	2,056	1,097
Miscellaneous - net	1,228	(735)	865	(622)
TOTAL	8,015	1,640	14,415	3,969
INTEREST EXPENSE
Interest expense	20,153	21,835	42,613	43,886
Allowance for borrowed funds used during construction	(3,256)	(1,033)	(5,836)	(1,971)
TOTAL	16,897	20,802	36,777	41,915
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	27,140	39,475	30,401	61,773
Income taxes	(11,796)	8,686	(29,877)	13,634
Net Income (Loss) Available to Common Stockholders, Basic	38,936	30,789	60,278	48,139
Entergy Texas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	363,580	403,486	704,054	752,426
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	171,133	150,568	312,001	310,260
System Energy [Member]
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	21,026	2,030	42,587	30,455
Nuclear refueling outage expenses	8,415	2,820	16,601	6,792
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	52,468	48,695	97,750	94,034
Decommissioning	8,888	8,541	17,687	16,998
Taxes, Other	7,176	6,866	14,715	13,963
Other Depreciation and Amortization	26,574	33,467	53,148	66,788
Other regulatory charges (credits) - net	(9,838)	(13,369)	(19,043)	(22,478)
Costs and Expenses	114,709	89,050	223,445	206,552
OPERATING INCOME	24,300	23,406	55,668	54,347
OTHER INCOME
Allowance for equity funds used during construction	1,678	2,904	3,267	5,004
Investment Income, Net	6,371	2,943	13,362	9,829
Miscellaneous - net	(1,490)	(1,794)	(2,718)	(2,970)
TOTAL	6,559	4,053	13,911	11,863
INTEREST EXPENSE
Interest expense	8,524	9,656	17,921	18,981
Allowance for borrowed funds used during construction	(410)	(736)	(799)	(1,268)
TOTAL	8,114	8,920	17,122	17,713
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	22,745	18,539	52,457	48,497
Income taxes	(1,727)	(4,848)	4,407	2,802
Net Income (Loss) Available to Common Stockholders, Basic	24,472	23,387	48,050	45,695
System Energy [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 139,009	$ 112,456	$ 279,113	$ 260,899

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Proceeds from Sale of Productive Assets	$ 19,801	$ 9,163
OPERATING ACTIVITIES
Consolidated net income	499,180	385,059
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	1,068,807	1,027,609
Deferred income taxes, investment tax credits, and non-current taxes accrued	225,749	88,732
Impairment of Long-Lived Assets Held-for-use	26,684	51,503
Changes in working capital:
Receivables	(127,259)	(45,515)
Fuel inventory	(13,346)	8,512
Accounts payable	(18,832)	97,464
Taxes accrued	(38,186)	(8,092)
Interest accrued	(144)	(2,056)
Deferred fuel costs	31,796	(132,263)
Other working capital accounts	(51,782)	(134,982)
Changes in provisions for estimated losses	4,719	27,443
Changes in other regulatory assets	(135,936)	106,712
Increase (Decrease) in Regulatory Liabilities	107,882	(247,239)
Changes in pensions and other postretirement liabilities	(66,033)	(181,278)
Other Noncash Income (Expense)	(460,209)	38,314
Net cash flow provided by operating activities	1,053,090	1,079,923
INVESTING ACTIVITIES
Construction/capital expenditures	(2,095,520)	(1,885,419)
Allowance for equity funds used during construction	75,607	60,335
Nuclear fuel purchases	(54,523)	(90,321)
Payments for Nuclear Fuel	(54,523)	(90,321)
Payments to storm reserve escrow account	(4,623)	(2,744)
Decrease (increase) in other investments	51,073	(10,769)
Proceeds from nuclear decommissioning trust fund sales	2,487,915	1,801,170
Investment in nuclear decommissioning trust funds	(2,523,805)	(1,826,384)
Proceeds from insurance	7,040	10,523
Changes in securitization account	12,034	4,754
Net cash flow used in investing activities	(2,025,001)	(1,929,692)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	5,391,547	3,359,193
Common stock and treasury stock	57,797	3,691
Proceeds from Issuance of Common Stock	607,650	0
Retirement of long-term debt	(4,214,495)	(2,569,131)
Changes in credit borrowings and commercial paper - net	(306,877)	405,795
Payments for Repurchase of Preferred Stock and Preference Stock	50,000	0
Dividends paid:
Common stock	(345,452)	(321,821)
Preferred stock	(8,219)	(6,878)
Other	(5,106)	10,434
Net cash flow provided by financing activities	1,126,845	881,283
Net increase in cash and cash equivalents	154,934	31,514
Cash and cash equivalents at beginning of period	480,975	781,273
Cash and cash equivalents at end of period	635,909	812,787
Cash paid / (received) during the period for:
Interest - net of amount capitalized	388,566	362,629
Income taxes	(6,967)	14,145
Entergy Arkansas [Member]
OPERATING ACTIVITIES
Consolidated net income	89,420	118,811
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	231,968	221,935
Deferred income taxes, investment tax credits, and non-current taxes accrued	45,680	(32,906)
Changes in working capital:
Receivables	4,920	(6,091)
Fuel inventory	(4,707)	12,289
Accounts payable	(14,280)	(25,035)
Taxes accrued	(19,961)	66,500
Interest accrued	4,155	1,260
Deferred fuel costs	56,182	(5,896)
Other working capital accounts	23,275	(8,750)
Changes in provisions for estimated losses	11,619	12,453
Changes in other regulatory assets	(57,516)	8,587
Increase (Decrease) in Regulatory Liabilities	70,958	(111,600)
Changes in pensions and other postretirement liabilities	(12,487)	(37,601)
Other Noncash Income (Expense)	(75,672)	12,639
Net cash flow provided by operating activities	353,554	226,595
INVESTING ACTIVITIES
Construction/capital expenditures	(309,696)	(350,429)
Allowance for equity funds used during construction	6,964	8,732
Change in money pool receivable - net	(25,166)	(57,708)
Nuclear fuel purchases	(6,691)	(23,342)
Payments for Nuclear Fuel	(6,691)	(23,342)
Proceeds from sale of nuclear fuel	22,834	30,907
Proceeds from nuclear decommissioning trust fund sales	83,407	121,440
Investment in nuclear decommissioning trust funds	(93,516)	(128,598)
Proceeds from insurance	0	7,043
Changes in securitization account	834	(279)
Net cash flow used in investing activities	(321,030)	(392,234)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	659,913	464,544
Retirement of long-term debt	(361,823)	(206,843)
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	(714)
Other	(1,052)	1,615
Net cash flow provided by financing activities	(700)	392,491
Net increase in cash and cash equivalents	31,824	226,852
Cash and cash equivalents at beginning of period	119	6,216
Cash and cash equivalents at end of period	31,943	233,068
Cash paid / (received) during the period for:
Interest - net of amount capitalized	62,486	56,900
Proceeds from Contributions from Parent	0	350,000
Entergy Louisiana [Member]
OPERATING ACTIVITIES
Consolidated net income	310,717	295,952
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	316,343	323,188
Deferred income taxes, investment tax credits, and non-current taxes accrued	99,015	119,378
Changes in working capital:
Receivables	(75,330)	(23,815)
Fuel inventory	(1,651)	(2,581)
Accounts payable	(25,686)	17,324
Taxes accrued	46,654	(56,076)
Interest accrued	1,918	790
Deferred fuel costs	(40,096)	(68,741)
Other working capital accounts	(64,715)	(6,053)
Changes in provisions for estimated losses	1,612	5,803
Changes in other regulatory assets	(88,911)	42,203
Increase (Decrease) in Regulatory Liabilities	26,565	(8,811)
Changes in pensions and other postretirement liabilities	(7,513)	(32,970)
Other Noncash Income (Expense)	(25,702)	(22,399)
Net cash flow provided by operating activities	473,220	583,192
INVESTING ACTIVITIES
Construction/capital expenditures	(900,264)	(880,785)
Allowance for equity funds used during construction	44,585	36,869
Change in money pool receivable - net	9,633	4,394
Nuclear fuel purchases	(63,026)	(14,740)
Payments for Nuclear Fuel	(63,026)	(14,740)
Proceeds from sale of nuclear fuel	0	36,301
Payments to storm reserve escrow account	(3,382)	(1,984)
Proceeds from nuclear decommissioning trust fund sales	195,433	169,407
Investment in nuclear decommissioning trust funds	(211,083)	(189,721)
Proceeds from insurance	7,040	3,480
Changes in securitization account	406	(1,423)
Net cash flow used in investing activities	(920,658)	(838,202)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	1,883,990	1,088,941
Retirement of long-term debt	(1,332,807)	(744,222)
Changes in credit borrowings and commercial paper - net	0	(43,540)
Dividends paid:
Common stock	(102,000)	(56,000)
Other	(370)	2,952
Net cash flow provided by financing activities	448,813	248,131
Net increase in cash and cash equivalents	1,375	(6,879)
Cash and cash equivalents at beginning of period	43,364	35,907
Cash and cash equivalents at end of period	44,739	29,028
Cash paid / (received) during the period for:
Interest - net of amount capitalized	146,256	138,625
Income taxes	0	(2,973)
Entergy Mississippi [Member]
OPERATING ACTIVITIES
Consolidated net income	42,065	61,085
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	78,806	76,541
Deferred income taxes, investment tax credits, and non-current taxes accrued	19,924	29,577
Changes in working capital:
Receivables	(6,288)	(32,365)
Fuel inventory	(4,265)	(977)
Accounts payable	4,545	29,476
Taxes accrued	(46,815)	(45,736)
Interest accrued	2,022	(3,792)
Deferred fuel costs	26,126	6,532
Other working capital accounts	1,850	(9,698)
Changes in provisions for estimated losses	(6,274)	7,242
Changes in other regulatory assets	(13,248)	(666)
Increase (Decrease) in Regulatory Liabilities	(17,754)	(127,047)
Changes in pensions and other postretirement liabilities	(3,323)	(9,336)
Other Noncash Income (Expense)	(6,402)	125,982
Net cash flow provided by operating activities	70,969	106,818
INVESTING ACTIVITIES
Construction/capital expenditures	(210,263)	(187,219)
Allowance for equity funds used during construction	4,262	4,100
Change in money pool receivable - net	(65,380)	1,633
Decrease (increase) in other investments	(310)	(863)
Net cash flow used in investing activities	(271,691)	(182,349)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	293,051	0
Change in money pool payable - net	0	63,394
Dividends paid:
Preferred stock	0	(477)
Other	(4,835)	6,536
Net cash flow provided by financing activities	288,216	69,453
Net increase in cash and cash equivalents	87,494	(6,078)
Cash and cash equivalents at beginning of period	36,954	6,096
Cash and cash equivalents at end of period	124,448	18
Cash paid / (received) during the period for:
Interest - net of amount capitalized	26,563	30,490
Entergy New Orleans [Member]
OPERATING ACTIVITIES
Consolidated net income	22,026	29,151
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	28,390	27,697
Deferred income taxes, investment tax credits, and non-current taxes accrued	15,053	22,813
Changes in working capital:
Receivables	(9,614)	(10,930)
Fuel inventory	(336)	1,833
Accounts payable	(3,412)	5,073
Taxes accrued	(6,189)	(10,602)
Interest accrued	(289)	(459)
Deferred fuel costs	2,028	(27,056)
Other working capital accounts	(13,204)	(9,524)
Changes in provisions for estimated losses	399	438
Changes in other regulatory assets	(16,470)	11,957
Increase (Decrease) in Regulatory Liabilities	(8,574)	3,042
Changes in pensions and other postretirement liabilities	(3,627)	(7,725)
Other Noncash Income (Expense)	23,184	(1,769)
Net cash flow provided by operating activities	29,365	33,939
INVESTING ACTIVITIES
Construction/capital expenditures	(105,545)	(85,324)
Allowance for equity funds used during construction	4,976	2,068
Change in money pool receivable - net	22,016	12,723
Payments to storm reserve escrow account	(931)	(544)
Receipts from storm reserve escrow account	0	3
Changes in securitization account	768	(11)
Net cash flow used in investing activities	(78,716)	(71,085)
Proceeds from the issuance of:
Retirement of long-term debt	(5,420)	(5,342)
Change in money pool payable - net	36,303	23,080
Dividends paid:
Common stock	0	(14,500)
Other	(910)	1,193
Net cash flow provided by financing activities	29,973	4,431
Net increase in cash and cash equivalents	(19,378)	(32,715)
Cash and cash equivalents at beginning of period	19,677	32,741
Cash and cash equivalents at end of period	299	26
Cash paid / (received) during the period for:
Interest - net of amount capitalized	11,726	10,483
Entergy Texas [Member]
OPERATING ACTIVITIES
Consolidated net income	60,278	48,139
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	74,349	61,907
Deferred income taxes, investment tax credits, and non-current taxes accrued	8,895	(19,785)
Changes in working capital:
Receivables	25,236	(25,987)
Fuel inventory	(589)	(1,710)
Accounts payable	(15,596)	906
Taxes accrued	(9,091)	20,439
Interest accrued	(7,787)	(678)
Deferred fuel costs	(12,445)	(37,103)
Other working capital accounts	1,998	9,614
Changes in provisions for estimated losses	(3,294)	434
Changes in other regulatory assets	28,742	39,592
Increase (Decrease) in Regulatory Liabilities	(50,817)	10,072
Changes in pensions and other postretirement liabilities	(3,899)	(13,330)
Other Noncash Income (Expense)	10,897	(2,031)
Net cash flow provided by operating activities	106,877	90,479
INVESTING ACTIVITIES
Construction/capital expenditures	(424,229)	(169,856)
Allowance for equity funds used during construction	11,551	3,562
Change in money pool receivable - net	0	34,902
Changes in securitization account	10,027	6,467
Net cash flow used in investing activities	(402,651)	(124,925)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	691,808	0
Retirement of long-term debt	(541,442)	(39,722)
Change in money pool payable - net	146,275	0
Dividends paid:
Other	924	(946)
Net cash flow provided by financing activities	297,565	(40,668)
Net increase in cash and cash equivalents	1,791	(75,114)
Cash and cash equivalents at beginning of period	56	115,513
Cash and cash equivalents at end of period	1,847	40,399
Cash paid / (received) during the period for:
Interest - net of amount capitalized	49,229	43,188
Income taxes	2,292	(624)
System Energy [Member]
OPERATING ACTIVITIES
Consolidated net income	48,050	45,695
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	106,972	109,682
Deferred income taxes, investment tax credits, and non-current taxes accrued	4,799	7,010
Changes in working capital:
Receivables	(15,402)	14,093
Accounts payable	(6,770)	32,681
Taxes accrued	(3,196)	(7,100)
Interest accrued	(1,275)	785
Other working capital accounts	1,205	(64,758)
Changes in other regulatory assets	(7,238)	(16,939)
Increase (Decrease) in Regulatory Liabilities	87,502	(12,894)
Changes in pensions and other postretirement liabilities	(2,121)	(6,551)
Other Noncash Income (Expense)	(82,150)	21,056
Net cash flow provided by operating activities	130,376	122,760
INVESTING ACTIVITIES
Construction/capital expenditures	(58,714)	(105,035)
Allowance for equity funds used during construction	3,267	5,004
Change in money pool receivable - net	35,588	47,531
Nuclear fuel purchases	(1,964)	(99,164)
Payments for Nuclear Fuel	(1,964)	(99,164)
Proceeds from sale of nuclear fuel	18,280	0
Proceeds from nuclear decommissioning trust fund sales	190,975	199,403
Investment in nuclear decommissioning trust funds	(200,909)	(206,695)
Net cash flow used in investing activities	(13,477)	(158,956)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	847,380	99,985
Retirement of long-term debt	(888,003)	(50,002)
Changes in credit borrowings and commercial paper - net	0	21,043
Dividends paid:
Common stock	(88,000)	(63,240)
Net cash flow provided by financing activities	(128,623)	7,786
Net increase in cash and cash equivalents	(11,724)	(28,410)
Cash and cash equivalents at beginning of period	95,685	287,187
Cash and cash equivalents at end of period	83,961	258,777
Cash paid / (received) during the period for:
Interest - net of amount capitalized	$ 12,462	$ 8,592

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Dec. 31, 2017
Cash and cash equivalents:
Cash	$ 61,200	$ 56,690
Temporary cash investments	574,709	424,285
Total cash and cash equivalents	635,909	480,975	$ 812,787	$ 781,273
Securitization recovery trust account	39,000	51,000
Accounts receivable:
Customer	653,027	558,494
Allowance for doubtful accounts	(6,965)	(7,322)
Other	130,483	167,722
Accrued unbilled revenues	458,079	395,511
Total accounts receivable	1,234,624	1,114,405
Deferred fuel costs	8,685	27,251
Fuel inventory - at average cost	130,650	117,304
Public Utilities, Inventory	787,068	752,843
Deferred nuclear refueling outage costs	219,269	230,960
Prepaid Expense and Other Assets, Current	267,303	234,326
TOTAL	3,283,508	2,958,064
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	7,069,264	6,920,164
Non-utility property - at cost (less accumulated depreciation)	324,366	304,382
Other	443,639	437,265
TOTAL	7,837,269	7,661,811
PROPERTY, PLANT, AND EQUIPMENT
Electric	52,015,373	49,831,486
Natural gas	517,044	496,150
Construction work in progress	2,678,681	2,888,639
Nuclear fuel	756,551	861,272
TOTAL PROPERTY, PLANT, AND EQUIPMENT	55,967,649	54,077,547
Less - accumulated depreciation and amortization	22,422,914	22,103,101
PROPERTY, PLANT, AND EQUIPMENT - NET	33,544,735	31,974,446
Regulatory assets:
Other regulatory assets	4,882,432	4,746,496
Deferred Fuel Cost Non Current	239,694	239,496
Goodwill	377,172	377,172
Deferred Income Tax Assets, Net	67,880	54,593
Other	333,055	262,988
Deferred Costs and Other Assets	5,900,233	5,680,745
TOTAL ASSETS	50,565,745	48,275,066
CURRENT LIABILITIES
Currently maturing long-term debt	150,010	650,009
Short-term borrowings	1,635,462	1,942,339
Accounts payable	1,412,607	1,496,058
Customer deposits	409,531	411,505
Taxes Payable, Current	216,055	254,241
Interest accrued	193,047	193,192
Deferred fuel costs	65,823	52,396
Pension and other postretirement liabilities	55,054	61,240
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	189,273	248,127
Other	195,746	134,437
TOTAL	4,522,608	5,443,544
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	4,391,250	4,107,152
Accumulated deferred investment tax credits	208,925	213,101
Regulatory liability for income taxes - net	1,726,770	1,817,021
Other regulatory liabilities	1,877,241	1,620,254
Decommissioning and asset retirement cost liabilities	6,788,363	6,355,543
Loss Contingency Accrual	518,721	514,107
Pension and other postretirement liabilities	2,556,238	2,616,085
Long-term debt	17,204,288	15,518,303
Deferred Credits and Other Liabilities	754,411	1,006,249
TOTAL	36,026,207	33,767,815
Subsidiaries' preferred stock without sinking fund	219,427	219,402
Common Shareholders' Equity:
Common Stock, Value, Issued	2,700	2,616
Additional Paid in Capital, Common Stock	6,539,533	5,951,431
Accumulated other comprehensive loss	(430,404)	(557,173)	(613,642)	(23,531)
Less - treasury stock, at cost	5,187,791	5,273,719
TOTAL	9,797,503	8,844,305	8,022,461	7,992,515
Retained Earnings (Accumulated Deficit)	8,873,465	8,721,150
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	50,565,745	48,275,066
Entergy Arkansas [Member]
Cash and cash equivalents:
Cash	2,795	118
Temporary cash investments	29,148	1
Total cash and cash equivalents	31,943	119	233,068	6,216
Securitization recovery trust account	3,831	4,666
Accounts receivable:
Customer	119,183	94,348
Allowance for doubtful accounts	(1,066)	(1,264)
Associated companies	56,244	48,184
Other	36,059	64,393
Accrued unbilled revenues	123,579	108,092
Total accounts receivable	333,999	313,753
Deferred fuel costs	0	19,235
Fuel inventory - at average cost	27,855	23,148
Public Utilities, Inventory	211,874	196,314
Deferred nuclear refueling outage costs	44,868	78,966
Prepaid Expense and Other Assets, Current	19,682	14,553
TOTAL	674,052	650,754
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,031,762	912,049
Other	5,477	5,480
TOTAL	1,037,239	917,529
PROPERTY, PLANT, AND EQUIPMENT
Electric	11,860,519	11,611,041
Construction work in progress	327,273	243,731
Nuclear fuel	202,998	220,602
TOTAL PROPERTY, PLANT, AND EQUIPMENT	12,390,790	12,075,374
Less - accumulated depreciation and amortization	4,926,197	4,864,818
PROPERTY, PLANT, AND EQUIPMENT - NET	7,464,593	7,210,556
Regulatory assets:
Other regulatory assets	1,592,493	1,534,977
Deferred Fuel Cost Non Current	67,492	67,294
Other	22,704	20,486
Deferred Costs and Other Assets	1,682,689	1,622,757
TOTAL ASSETS	10,858,573	10,401,596
CURRENT LIABILITIES
Associated companies accounts payable	68,185	251,768
Accounts payable	191,038	187,387
Customer deposits	100,284	99,053
Taxes Payable, Current	36,928	56,889
Interest accrued	23,048	18,893
Deferred fuel costs	37,145	0
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	75,139	99,316
Other	45,402	23,943
TOTAL	577,169	737,249
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	1,127,393	1,085,545
Accumulated deferred investment tax credits	32,302	32,903
Regulatory liability for income taxes - net	486,342	505,748
Other regulatory liabilities	517,209	402,668
Decommissioning and asset retirement cost liabilities	1,207,514	1,048,428
Loss Contingency Accrual	60,598	48,979
Pension and other postretirement liabilities	300,760	313,295
Long-term debt	3,527,146	3,225,759
Deferred Credits and Other Liabilities	64,617	17,919
TOTAL	7,323,881	6,681,244
Common Shareholders' Equity:
Members' Equity	2,957,523	2,983,103
TOTAL	2,957,523	2,983,103	2,844,851	2,376,754
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	10,858,573	10,401,596
Entergy Louisiana [Member]
Cash and cash equivalents:
Cash	252	252
Temporary cash investments	44,487	43,112
Total cash and cash equivalents	44,739	43,364	29,028	35,907
Securitization recovery trust account	3,200	3,600
Accounts receivable:
Customer	259,321	199,903
Allowance for doubtful accounts	(1,919)	(1,813)
Associated companies	109,752	123,363
Other	48,165	60,879
Accrued unbilled revenues	192,722	167,052
Total accounts receivable	608,041	549,384
Deferred fuel costs	8,685	0
Fuel inventory - at average cost	36,069	34,418
Public Utilities, Inventory	333,943	324,627
Deferred nuclear refueling outage costs	85,483	24,406
Prepaid Expense and Other Assets, Current	44,682	38,715
TOTAL	1,161,642	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	1,461,061	1,284,996
Non-utility property - at cost (less accumulated depreciation)	305,964	286,555
Storm Reserve Escrow Account	292,907	289,525
Other	15,302	14,927
TOTAL	3,465,821	3,266,590
PROPERTY, PLANT, AND EQUIPMENT
Electric	21,957,846	20,532,312
Natural gas	224,044	211,421
Construction work in progress	1,294,844	1,864,582
Nuclear fuel	302,982	298,022
TOTAL PROPERTY, PLANT, AND EQUIPMENT	23,779,716	22,906,337
Less - accumulated depreciation and amortization	8,907,647	8,837,596
PROPERTY, PLANT, AND EQUIPMENT - NET	14,872,069	14,068,741
Regulatory assets:
Other regulatory assets	1,193,988	1,105,077
Deferred Fuel Cost Non Current	168,122	168,122
Other	33,429	28,371
Deferred Costs and Other Assets	1,395,539	1,301,570
TOTAL ASSETS	20,895,071	19,651,815
CURRENT LIABILITIES
Currently maturing long-term debt	2	2
Associated companies accounts payable	87,090	102,749
Accounts payable	330,748	390,367
Customer deposits	153,705	155,314
Taxes Payable, Current	77,522	30,868
Interest accrued	85,368	83,450
Deferred fuel costs	0	31,411
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	35,532	31,457
Other	76,596	49,202
TOTAL	846,563	874,820
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	2,334,983	2,226,721
Accumulated deferred investment tax credits	114,564	116,999
Regulatory liability for income taxes - net	545,272	581,001
Other regulatory liabilities	807,002	748,784
Decommissioning and asset retirement cost liabilities	1,460,783	1,280,272
Loss Contingency Accrual	312,367	310,755
Pension and other postretirement liabilities	635,488	643,171
Long-term debt	7,359,933	6,805,766
Deferred Credits and Other Liabilities	368,444	160,608
TOTAL	13,938,836	12,874,077
Common Shareholders' Equity:
Accumulated other comprehensive loss	(8,091)	(6,153)
Members' Equity	6,117,763	5,909,071
TOTAL	6,109,672	5,902,918	5,543,980	5,308,804
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	20,895,071	19,651,815
Entergy Mississippi [Member]
Cash and cash equivalents:
Cash	791	11
Temporary cash investments	123,657	36,943
Total cash and cash equivalents	124,448	36,954	18	6,096
Accounts receivable:
Customer	74,761	73,205
Allowance for doubtful accounts	(488)	(563)
Associated companies	112,850	51,065
Other	10,975	8,647
Accrued unbilled revenues	56,095	50,171
Total accounts receivable	254,193	182,525
Deferred fuel costs	0	8,016
Fuel inventory - at average cost	16,196	11,931
Public Utilities, Inventory	49,665	47,255
Prepaid Expense and Other Assets, Current	9,118	9,365
TOTAL	453,620	296,046
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,568	4,576
Escrow accounts	32,756	32,447
TOTAL	37,324	37,023
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,884,462	4,780,720
Construction work in progress	179,763	128,149
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,064,225	4,908,869
Less - accumulated depreciation and amortization	1,650,732	1,641,821
PROPERTY, PLANT, AND EQUIPMENT - NET	3,413,493	3,267,048
Regulatory assets:
Other regulatory assets	356,297	343,049
Other	12,799	3,638
Deferred Costs and Other Assets	369,096	346,687
TOTAL ASSETS	4,273,533	3,946,804
CURRENT LIABILITIES
Currently maturing long-term debt	150,000	150,000
Associated companies accounts payable	41,245	42,928
Accounts payable	82,727	79,117
Customer deposits	86,238	85,085
Taxes Payable, Current	30,737	77,552
Interest accrued	22,253	20,231
Deferred fuel costs	18,110	0
Other	18,057	7,526
TOTAL	449,367	462,439
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	576,233	551,869
Accumulated deferred investment tax credits	10,106	10,186
Regulatory liability for income taxes - net	241,939	246,402
Other regulatory liabilities	20,331	33,622
Decommissioning and asset retirement cost liabilities	9,463	9,206
Loss Contingency Accrual	44,868	51,142
Pension and other postretirement liabilities	89,688	93,100
Long-term debt	1,469,420	1,175,750
Deferred Credits and Other Liabilities	27,827	20,862
TOTAL	2,489,875	2,192,139
Common Shareholders' Equity:
Members' Equity	1,334,291	1,292,226
TOTAL	1,334,291	1,292,226	1,238,478	1,177,870
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	4,273,533	3,946,804
Entergy New Orleans [Member]
Cash and cash equivalents:
Cash	299	26
Temporary cash investments	0	19,651
Total cash and cash equivalents	299	19,677	26	32,741
Securitization recovery trust account	1,457	2,224
Accounts receivable:
Customer	53,204	43,890
Allowance for doubtful accounts	(3,063)	(3,222)
Associated companies	1,693	27,938
Other	6,219	4,090
Accrued unbilled revenues	21,148	18,907
Total accounts receivable	79,201	91,603
Fuel inventory - at average cost	1,869	1,533
Public Utilities, Inventory	12,276	12,133
Prepaid Expense and Other Assets, Current	18,501	6,905
TOTAL	113,603	134,075
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	1,016	1,016
Storm Reserve Escrow Account	81,784	80,853
TOTAL	82,800	81,869
PROPERTY, PLANT, AND EQUIPMENT
Electric	1,388,533	1,364,091
Natural gas	293,000	284,728
Construction work in progress	194,846	146,668
TOTAL PROPERTY, PLANT, AND EQUIPMENT	1,876,379	1,795,487
Less - accumulated depreciation and amortization	687,877	670,135
PROPERTY, PLANT, AND EQUIPMENT - NET	1,188,502	1,125,352
Regulatory assets:
Other regulatory assets	246,266	229,796
Deferred Fuel Cost Non Current	4,080	4,080
Other	2,919	1,416
Deferred Costs and Other Assets	253,265	235,292
TOTAL ASSETS	1,638,170	1,576,588
CURRENT LIABILITIES
Notes Payable, Related Parties, Current	1,979	1,979
Associated companies accounts payable	79,296	43,416
Accounts payable	37,871	36,686
Customer deposits	28,647	28,667
Taxes Payable, Current	0	4,068
Interest accrued	6,077	6,366
Deferred fuel costs	3,316	1,288
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	23,211	25,301
Other	7,835	9,521
TOTAL	188,232	157,292
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	342,071	323,595
Accumulated deferred investment tax credits	2,175	2,219
Regulatory liability for income taxes - net	54,707	60,249
Decommissioning and asset retirement cost liabilities	3,405	3,291
Loss Contingency Accrual	86,993	86,594
Pension and other postretirement liabilities	1,999	5,626
Long-term debt	462,168	467,358
Notes Payable, Related Parties, Noncurrent	14,367	14,367
Deferred Credits and Other Liabilities	15,077	11,047
TOTAL	982,962	974,346
Common Shareholders' Equity:
Members' Equity	466,976	444,950
TOTAL	466,976	444,950	430,199	415,548
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	1,638,170	1,576,588
Entergy Texas [Member]
Cash and cash equivalents:
Cash	1,816	26
Temporary cash investments	31	30
Total cash and cash equivalents	1,847	56	40,399	115,513
Securitization recovery trust account	30,159	40,185
Accounts receivable:
Customer	78,561	69,714
Allowance for doubtful accounts	(429)	(461)
Associated companies	19,121	64,441
Other	10,233	12,275
Accrued unbilled revenues	64,535	51,288
Total accounts receivable	172,021	197,257
Fuel inventory - at average cost	43,256	42,667
Public Utilities, Inventory	43,697	41,883
Prepaid Expense and Other Assets, Current	6,852	15,903
TOTAL	297,832	337,951
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	424	448
Non-utility property - at cost (less accumulated depreciation)	376	376
Other	19,647	19,218
TOTAL	20,447	20,042
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,958,751	4,773,984
Construction work in progress	514,289	325,193
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,473,040	5,099,177
Less - accumulated depreciation and amortization	1,716,977	1,684,569
PROPERTY, PLANT, AND EQUIPMENT - NET	3,756,063	3,414,608
Regulatory assets:
Other regulatory assets	569,306	598,048
Other	31,235	29,371
Deferred Costs and Other Assets	600,541	627,419
TOTAL ASSETS	4,674,883	4,400,020
CURRENT LIABILITIES
Currently maturing long-term debt	0	500,000
Associated companies accounts payable	215,725	119,371
Accounts payable	181,804	150,679
Customer deposits	40,657	43,387
Taxes Payable, Current	44,422	53,513
Interest accrued	16,568	24,355
Deferred fuel costs	7,252	19,697
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	55,391	87,627
Other	8,366	6,353
TOTAL	570,185	1,004,982
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	564,171	552,535
Accumulated deferred investment tax credits	10,867	11,176
Regulatory liability for income taxes - net	249,912	264,623
Other regulatory liabilities	44,014	47,884
Decommissioning and asset retirement cost liabilities	7,423	7,222
Loss Contingency Accrual	10,562	13,856
Pension and other postretirement liabilities	905	4,834
Long-term debt	1,664,936	1,013,735
Deferred Credits and Other Liabilities	69,228	56,771
TOTAL	2,622,018	1,972,636
Common Shareholders' Equity:
Common Stock, Value, Issued	49,452	49,452
Additional Paid in Capital, Common Stock	596,994	596,994
Retained Earnings (Accumulated Deficit)	836,234	775,956
TOTAL	1,482,680	1,422,402	1,308,306	1,260,167
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	4,674,883	4,400,020
System Energy [Member]
Cash and cash equivalents:
Cash	1,109	68
Temporary cash investments	82,852	95,617
Total cash and cash equivalents	83,961	95,685	258,777	287,187
Accounts receivable:
Associated companies	128,409	148,571
Other	5,366	5,390
Total accounts receivable	133,775	153,961
Public Utilities, Inventory	103,902	97,225
Deferred nuclear refueling outage costs	28,129	44,424
Prepaid Expense and Other Assets, Current	11,399	2,985
Prepaid Taxes	8,611	5,415
TOTAL	369,777	399,695
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	986,761	869,543
TOTAL	986,761	869,543
PROPERTY, PLANT, AND EQUIPMENT
Electric	5,033,870	5,036,116
Construction work in progress	107,187	70,156
Nuclear fuel	167,886	234,889
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,308,943	5,341,161
Less - accumulated depreciation and amortization	3,249,715	3,212,080
PROPERTY, PLANT, AND EQUIPMENT - NET	2,059,228	2,129,081
Regulatory assets:
Other regulatory assets	453,609	446,371
Other	3,937	4,124
Deferred Costs and Other Assets	457,546	450,495
TOTAL ASSETS	3,873,312	3,848,814
CURRENT LIABILITIES
Currently maturing long-term debt	8	6
Associated companies accounts payable	4,936	11,031
Accounts payable	40,273	47,565
Interest accrued	12,020	13,295
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	0	4,426
Other	2,833	2,832
TOTAL	60,070	79,155
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	815,895	805,296
Accumulated deferred investment tax credits	38,034	38,673
Regulatory liability for income taxes - net	148,598	158,998
Other regulatory liabilities	484,215	381,887
Decommissioning and asset retirement cost liabilities	913,687	896,000
Pension and other postretirement liabilities	96,518	98,639
Long-term debt	590,638	630,744
Deferred Credits and Other Liabilities	28,409	22,224
TOTAL	3,115,994	3,032,461
Common Shareholders' Equity:
Common Stock, Value, Issued	601,850	601,850
Retained Earnings (Accumulated Deficit)	95,398	135,348
TOTAL	697,248	737,198	$ 693,264	$ 710,809
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$ 3,873,312	$ 3,848,814

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Securitization property	$ 306,864	$ 360,790
Securitization bonds	$ 359,938	$ 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	71,349,066	72,530,866
Entergy Arkansas [Member]
Securitization property	$ 8,594	$ 14,329
Securitization bonds	13,939	20,898
Entergy Louisiana [Member]
Securitization property	39,603	49,753
Securitization bonds	45,320	55,682
Entergy New Orleans [Member]
Securitization property	55,707	60,453
Securitization bonds	58,322	63,620
Entergy Texas [Member]
Securitization property	202,972	236,336
Securitization bonds	$ 242,357	$ 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 Arkansas [Member]	Entergy Louisiana [Member]	Entergy Louisiana [Member]Member's Equity [Member]	Entergy Louisiana [Member]Accumulated Other Comprehensive Income [Member]	Entergy Mississippi [Member]	Entergy New Orleans [Member]	Entergy Texas [Member]	Entergy Texas [Member]Paid In Capital [Member]	Entergy Texas [Member]Retained Earnings [Member]	Entergy Texas [Member]Common Stock [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)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest								$ 2,376,754	$ 5,308,804	$ 5,355,204	$ (46,400)	$ 1,177,870	$ 415,548	$ 1,260,167	$ 596,994	$ 613,721	$ 49,452	$ 710,809	$ 52,459	$ 658,350
Consolidated net income	385,059	6,878	0	378,181	0	0	0	118,811	295,952	295,952	0	61,085	29,151	48,139	0	48,139	0	45,695	45,695	0
Dividends, Preferred Stock, Cash								714				477
Dividends, Common Stock, Cash	(321,821)	0	0	(321,821)	0	0	0		(56,000)	(56,000)	0		(14,500)					(63,240)	(6,740)	(56,500)
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	6,878	6,878	0	0	0	0	0	714				477
Other comprehensive income (loss)	27,001	0	0	0	27,001	0	0		(1,002)	0	(1,002)
Common stock issuances related to stock plans	(19,483)	0	4,029	0	0	0	(23,512)
Other									13	13	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)
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)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest								2,844,851	5,543,980	5,601,431	(57,451)	1,238,478	430,199	1,308,306	596,994	661,860	49,452	693,264	91,414	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)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest								2,983,103	5,902,918	5,909,071	(6,153)	1,292,226	444,950	1,422,402	596,994	775,956	49,452	737,198	135,348	601,850
Consolidated net income	499,180	8,219	0	490,961	0	0	0	89,420	310,717	310,717	0	42,065	22,026	60,278	0	60,278	0	48,050	48,050	0
Dividends, Common Stock, Cash	(345,452)	0	0	(345,452)	0	0	0	(115,000)	(102,000)	(102,000)	0							(88,000)	(88,000)	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	8,219	8,219	0	0	0	0	0	0				0
Other comprehensive income (loss)	133,575	0	0	0	133,575	0	0		(1,938)	0	(1,938)
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	(66,471)	0	19,457	0	0	0	(85,928)
Other									(25)	(25)	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)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest								$ 2,957,523	$ 6,109,672	$ 6,117,763	$ (8,091)	$ 1,334,291	$ 466,976	$ 1,482,680	$ 596,994	$ 836,234	$ 49,452	$ 697,248	$ 95,398	$ 601,850

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Net income	$ 240,533	$ 248,860	$ 499,180	$ 385,059
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss)	94,982	(65,068)	82,556	30,359
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	11,496	15,565	23,046	32,139
Net unrealized investment gains	14,270	(2,641)	27,973	(35,497)
Other comprehensive income (loss)	120,748	(52,144)	133,575	27,001
Total comprehensive income	361,281	196,716	632,755	412,060
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	4,109	3,439	8,219	6,878
Comprehensive Income Attributable to Entergy Corporation	357,172	193,277	624,536	405,182
Entergy Louisiana [Member]
Net income	183,084	184,358	310,717	295,952
Other comprehensive income (loss)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	(969)	(501)	(1,938)	(1,002)
Other comprehensive income (loss)	(969)	(501)	(1,938)	(1,002)
Total comprehensive income	$ 182,115	$ 183,857	$ 308,779	$ 294,950

Consolidated Statements Of Co_2

Consolidated Statements Of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Tax	$ 25,242	$ (17,312)	$ 19,890	$ 8,037
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	3,077	4,225	6,326	8,793
Other Comprehensive Income (Loss), Securities, Available-for-sale, Tax	8,096	(2,842)	16,169	2,533
Entergy Louisiana [Member]
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	$ (342)	$ (177)	$ (684)	$ (353)

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 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. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. 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. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. 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. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. 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. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. 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. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. 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. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. 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. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. 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	6 Months Ended
	Jun. 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. A procedural schedule has been set to address the report and contested issues, with a hearing scheduled in November 2019. 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. The defendants have denied the allegations. 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 is scheduled for August 2019. 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. The proposed new formula rates would go into effect in January 2020. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing 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. Commercial operation at St. Charles Power Station commenced in May 2019. 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 will decrease as a result of this filing, overall formula rate plan revenues will increase 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 with resulting rates to be implemented in September 2019, subject to refund if there are 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. 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 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. 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 a $0.8 million increase 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, with a City Council decision on the matter expected by October 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. The letter also sets out proposed next steps to achieve a resolution of the proceeding. 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 . A hearing is scheduled for September 2019. 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 June 2019 the ALJ issued an order approving interim rates effective June 2019 at the level proposed in Entergy Texas’s application. The proceeding has been returned to the PUCT for approval of the settlement agreement filed in the proceeding, at which point the interim rates would become permanent. 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. 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 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 consolidated hearing has been scheduled for September 2019, and 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 staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC 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 staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC 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 staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020. Grand Gulf Sale-leaseback Renewal Complaint As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million ), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019. In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds. Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and ratepayers will save approximately $850 million over initial and renewal terms of the leases. System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain. System Energy’s testimony also challenged the refund calculations supplied by the other parties. Storm Cost Recovery Filings with Retail Regulators Entergy Mississippi As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million , the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million . As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million
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. A procedural schedule has been set to address the report and contested issues, with a hearing scheduled in November 2019. 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. The defendants have denied the allegations. 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 is scheduled for August 2019. 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. The proposed new formula rates would go into effect in January 2020. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing 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. Commercial operation at St. Charles Power Station commenced in May 2019. 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 will decrease as a result of this filing, overall formula rate plan revenues will increase 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 with resulting rates to be implemented in September 2019, subject to refund if there are 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. 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 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. 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 a $0.8 million increase 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, with a City Council decision on the matter expected by October 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. The letter also sets out proposed next steps to achieve a resolution of the proceeding. 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 . A hearing is scheduled for September 2019. 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 June 2019 the ALJ issued an order approving interim rates effective June 2019 at the level proposed in Entergy Texas’s application. The proceeding has been returned to the PUCT for approval of the settlement agreement filed in the proceeding, at which point the interim rates would become permanent. 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. 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 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 consolidated hearing has been scheduled for September 2019, and 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 staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC 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 staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC 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 staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020. Grand Gulf Sale-leaseback Renewal Complaint As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million ), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019. In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds. Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and ratepayers will save approximately $850 million over initial and renewal terms of the leases. System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain. System Energy’s testimony also challenged the refund calculations supplied by the other parties. Storm Cost Recovery Filings with Retail Regulators Entergy Mississippi As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million , the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million . As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million
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. A procedural schedule has been set to address the report and contested issues, with a hearing scheduled in November 2019. 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. The defendants have denied the allegations. 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 is scheduled for August 2019. 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. The proposed new formula rates would go into effect in January 2020. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing 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. Commercial operation at St. Charles Power Station commenced in May 2019. 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 will decrease as a result of this filing, overall formula rate plan revenues will increase 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 with resulting rates to be implemented in September 2019, subject to refund if there are 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. 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 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. 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 a $0.8 million increase 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, with a City Council decision on the matter expected by October 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. The letter also sets out proposed next steps to achieve a resolution of the proceeding. 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 . A hearing is scheduled for September 2019. 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 June 2019 the ALJ issued an order approving interim rates effective June 2019 at the level proposed in Entergy Texas’s application. The proceeding has been returned to the PUCT for approval of the settlement agreement filed in the proceeding, at which point the interim rates would become permanent. 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. 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 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 consolidated hearing has been scheduled for September 2019, and 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 staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC 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 staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC 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 staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020. Grand Gulf Sale-leaseback Renewal Complaint As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million ), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019. In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds. Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and ratepayers will save approximately $850 million over initial and renewal terms of the leases. System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain. System Energy’s testimony also challenged the refund calculations supplied by the other parties. Storm Cost Recovery Filings with Retail Regulators Entergy Mississippi As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million , the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million . As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million
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. A procedural schedule has been set to address the report and contested issues, with a hearing scheduled in November 2019. 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. The defendants have denied the allegations. 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 is scheduled for August 2019. 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. The proposed new formula rates would go into effect in January 2020. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing 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. Commercial operation at St. Charles Power Station commenced in May 2019. 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 will decrease as a result of this filing, overall formula rate plan revenues will increase 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 with resulting rates to be implemented in September 2019, subject to refund if there are 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. 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 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. 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 a $0.8 million increase 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, with a City Council decision on the matter expected by October 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. The letter also sets out proposed next steps to achieve a resolution of the proceeding. 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 . A hearing is scheduled for September 2019. 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 June 2019 the ALJ issued an order approving interim rates effective June 2019 at the level proposed in Entergy Texas’s application. The proceeding has been returned to the PUCT for approval of the settlement agreement filed in the proceeding, at which point the interim rates would become permanent. 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. 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 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 consolidated hearing has been scheduled for September 2019, and 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 staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC 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 staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC 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 staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020. Grand Gulf Sale-leaseback Renewal Complaint As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million ), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019. In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds. Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and ratepayers will save approximately $850 million over initial and renewal terms of the leases. System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain. System Energy’s testimony also challenged the refund calculations supplied by the other parties. Storm Cost Recovery Filings with Retail Regulators Entergy Mississippi As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million , the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million . As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million
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. A procedural schedule has been set to address the report and contested issues, with a hearing scheduled in November 2019. 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. The defendants have denied the allegations. 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 is scheduled for August 2019. 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. The proposed new formula rates would go into effect in January 2020. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing 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. Commercial operation at St. Charles Power Station commenced in May 2019. 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 will decrease as a result of this filing, overall formula rate plan revenues will increase 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 with resulting rates to be implemented in September 2019, subject to refund if there are 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. 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 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. 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 a $0.8 million increase 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, with a City Council decision on the matter expected by October 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. The letter also sets out proposed next steps to achieve a resolution of the proceeding. 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 . A hearing is scheduled for September 2019. 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 June 2019 the ALJ issued an order approving interim rates effective June 2019 at the level proposed in Entergy Texas’s application. The proceeding has been returned to the PUCT for approval of the settlement agreement filed in the proceeding, at which point the interim rates would become permanent. 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. 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 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 consolidated hearing has been scheduled for September 2019, and 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 staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC 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 staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC 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 staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020. Grand Gulf Sale-leaseback Renewal Complaint As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million ), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019. In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds. Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and ratepayers will save approximately $850 million over initial and renewal terms of the leases. System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain. System Energy’s testimony also challenged the refund calculations supplied by the other parties. Storm Cost Recovery Filings with Retail Regulators Entergy Mississippi As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million , the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million . As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million
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. A procedural schedule has been set to address the report and contested issues, with a hearing scheduled in November 2019. 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. The defendants have denied the allegations. 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 is scheduled for August 2019. 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. The proposed new formula rates would go into effect in January 2020. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing 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. Commercial operation at St. Charles Power Station commenced in May 2019. 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 will decrease as a result of this filing, overall formula rate plan revenues will increase 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 with resulting rates to be implemented in September 2019, subject to refund if there are 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. 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 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. 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 a $0.8 million increase 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, with a City Council decision on the matter expected by October 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. The letter also sets out proposed next steps to achieve a resolution of the proceeding. 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 . A hearing is scheduled for September 2019. 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 June 2019 the ALJ issued an order approving interim rates effective June 2019 at the level proposed in Entergy Texas’s application. The proceeding has been returned to the PUCT for approval of the settlement agreement filed in the proceeding, at which point the interim rates would become permanent. 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. 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 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 consolidated hearing has been scheduled for September 2019, and 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 staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC 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 staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC 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 staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020. Grand Gulf Sale-leaseback Renewal Complaint As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million ), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019. In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds. Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and ratepayers will save approximately $850 million over initial and renewal terms of the leases. System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain. System Energy’s testimony also challenged the refund calculations supplied by the other parties. Storm Cost Recovery Filings with Retail Regulators Entergy Mississippi As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million , the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million . As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million
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. A procedural schedule has been set to address the report and contested issues, with a hearing scheduled in November 2019. 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. The defendants have denied the allegations. 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 is scheduled for August 2019. 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. The proposed new formula rates would go into effect in January 2020. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing 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. Commercial operation at St. Charles Power Station commenced in May 2019. 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 will decrease as a result of this filing, overall formula rate plan revenues will increase 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 with resulting rates to be implemented in September 2019, subject to refund if there are 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. 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 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. 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 a $0.8 million increase 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, with a City Council decision on the matter expected by October 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. The letter also sets out proposed next steps to achieve a resolution of the proceeding. 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 . A hearing is scheduled for September 2019. 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 June 2019 the ALJ issued an order approving interim rates effective June 2019 at the level proposed in Entergy Texas’s application. The proceeding has been returned to the PUCT for approval of the settlement agreement filed in the proceeding, at which point the interim rates would become permanent. 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. 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 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 consolidated hearing has been scheduled for September 2019, and 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 staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC 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 staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC 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 staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020. Grand Gulf Sale-leaseback Renewal Complaint As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million ), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019. In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds. Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and ratepayers will save approximately $850 million over initial and renewal terms of the leases. System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain. System Energy’s testimony also challenged the refund calculations supplied by the other parties. Storm Cost Recovery Filings with Retail Regulators Entergy Mississippi As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million , the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million . As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million

Equity

Equity	6 Months Ended
	Jun. 30, 2019
Equity	EQUITY (Entergy Corporation and Entergy Louisiana) 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 June 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 $236.4 193.0 $1.22 $245.4 180.8 $1.36 Average dilutive effect of: Stock options 0.5 — 0.3 — Other equity plans 0.7 — 0.7 (0.01 ) Equity forwards — — 1.2 (0.01 ) Diluted earnings per share $236.4 194.2 $1.22 $245.4 183.0 $1.34 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 June 30, 2018 . For the Six Months Ended June 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 $491.0 191.3 $2.57 $378.2 180.8 $2.09 Average dilutive effect of: Stock options 0.5 (0.01 ) 0.3 — Other equity plans 0.6 (0.01 ) 0.5 — Equity forwards 0.8 (0.01 ) 0.6 (0.01 ) Diluted earnings per share $491.0 193.2 $2.54 $378.2 182.2 $2.08 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.3 million for the six months ended June 30, 2019 and approximately 1.1 million for the six months ended June 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 June 30, 2019 and $0.89 for the three months ended June 30, 2018 . Dividends declared per common share were $1.82 for the six months ended June 30, 2019 and $1.78 for the six months ended June 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 six months ended June 30, 2019 , Entergy Corporation issued 1,181,800 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards. Entergy Corporation did not repurchase any of its common stock during the six months ended June 30, 2019 . Retained Earnings On July 26, 2019, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.91 per share, payable on September 3, 2019, to holders of record as of August 8, 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 June 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, April 1, 2019 ($43,246 ) ($520,372 ) $12,466 ($551,152 ) Other comprehensive income (loss) before reclassifications 99,359 — 15,834 115,193 Amounts reclassified from accumulated other comprehensive income (loss) (4,377 ) 11,496 (1,564 ) 5,555 Net other comprehensive income (loss) for the period 94,982 11,496 14,270 120,748 Ending balance, June 30, 2019 $51,736 ($508,876 ) $26,736 ($430,404 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 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, April 1, 2018 $50,194 ($605,491 ) ($6,201 ) ($561,498 ) Other comprehensive income (loss) before reclassifications (62,981 ) — (7,509 ) (70,490 ) Amounts reclassified from accumulated other comprehensive income (loss) (2,087 ) 15,565 4,868 18,346 Net other comprehensive income (loss) for the period (65,068 ) 15,565 (2,641 ) (52,144 ) Ending balance, June 30, 2018 ($14,874 ) ($589,926 ) ($8,842 ) ($613,642 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 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 127,670 — 29,373 157,043 Amounts reclassified from accumulated other comprehensive income (loss) (45,114 ) 23,046 (1,400 ) (23,468 ) Net other comprehensive income (loss) for the period 82,556 23,046 27,973 133,575 Ending balance, June 30, 2019 $51,736 ($508,876 ) $26,736 ($430,404 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 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 8,585 — (43,785 ) (35,200 ) Amounts reclassified from accumulated other comprehensive income (loss) 21,774 32,139 8,288 62,201 Net other comprehensive income (loss) for the period 30,359 32,139 (35,497 ) 27,001 Reclassification pursuant to ASU 2018-02 (7,756 ) (90,966 ) 114,227 15,505 Ending balance, June 30, 2018 ($14,874 ) ($589,926 ) ($8,842 ) ($613,642 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended June 30, 2019 and 2018: Pension and Other 2019 2018 (In Thousands) Beginning balance, April 1, ($7,122 ) ($56,950 ) Amounts reclassified from accumulated other (969 ) (501 ) Net other comprehensive income (loss) for the period (969 ) (501 ) Ending balance, June 30, ($8,091 ) ($57,451 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2019 and 2018: Pension and Other 2019 2018 (In Thousands) Beginning balance, January 1, ($6,153 ) ($46,400 ) Amounts reclassified from accumulated other (1,938 ) (1,002 ) Net other comprehensive income (loss) for the period (1,938 ) (1,002 ) Reclassification pursuant to ASU 2018-02 — (10,049 ) Ending balance, June 30, ($8,091 ) ($57,451 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended June 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 $5,589 $2,735 Competitive business operating revenues Interest rate swaps (48 ) (93 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 5,541 2,642 (1,164 ) (555 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $4,377 $2,087 Pension and other postretirement liabilities Amortization of prior-service credit $5,325 $5,424 (a) Amortization of loss (18,980 ) (24,808 ) (a) Settlement loss (918 ) (406 ) (a) Total amortization (14,573 ) (19,790 ) 3,077 4,225 Income taxes Total amortization (net of tax) ($11,496 ) ($15,565 ) Net unrealized investment gain (loss) Realized gain (loss) $2,475 ($7,702 ) Interest and investment income (911 ) 2,834 Income taxes Total realized investment gain (loss) (net of tax) $1,564 ($4,868 ) Total reclassifications for the period (net of tax) ($5,555 ) ($18,346 ) (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 six months ended June 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 $57,204 ($27,347 ) Competitive business operating revenues Interest rate swaps (97 ) (215 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 57,107 (27,562 ) (11,993 ) 5,788 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $45,114 ($21,774 ) Pension and other postretirement liabilities Amortization of prior-service credit $10,652 $10,850 (a) Amortization of loss (37,969 ) (49,760 ) (a) Settlement loss (2,055 ) (2,022 ) (a) Total amortization (29,372 ) (40,932 ) 6,326 8,793 Income taxes Total amortization (net of tax) ($23,046 ) ($32,139 ) Net unrealized investment gain (loss) Realized gain (loss) $2,216 ($13,114 ) Interest and investment income (816 ) 4,826 Income taxes Total realized investment gain (loss) (net of tax) $1,400 ($8,288 ) Total reclassifications for the period (net of tax) $23,468 ($62,201 ) (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 June 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 ) (1,256 ) (a) Total amortization 1,311 678 (342 ) (177 ) Income taxes Total amortization (net of tax) 969 501 Total reclassifications for the period (net of tax) $969 $501 (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 six months ended June 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 $3,674 $3,868 (a) Amortization of loss (1,052 ) (2,513 ) (a) Total amortization 2,622 1,355 (684 ) (353 ) Income taxes Total amortization (net of tax) 1,938 1,002 Total reclassifications for the period (net of tax) $1,938 $1,002 (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]
Equity	EQUITY (Entergy Corporation and Entergy Louisiana) 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 June 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 $236.4 193.0 $1.22 $245.4 180.8 $1.36 Average dilutive effect of: Stock options 0.5 — 0.3 — Other equity plans 0.7 — 0.7 (0.01 ) Equity forwards — — 1.2 (0.01 ) Diluted earnings per share $236.4 194.2 $1.22 $245.4 183.0 $1.34 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 June 30, 2018 . For the Six Months Ended June 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 $491.0 191.3 $2.57 $378.2 180.8 $2.09 Average dilutive effect of: Stock options 0.5 (0.01 ) 0.3 — Other equity plans 0.6 (0.01 ) 0.5 — Equity forwards 0.8 (0.01 ) 0.6 (0.01 ) Diluted earnings per share $491.0 193.2 $2.54 $378.2 182.2 $2.08 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.3 million for the six months ended June 30, 2019 and approximately 1.1 million for the six months ended June 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 June 30, 2019 and $0.89 for the three months ended June 30, 2018 . Dividends declared per common share were $1.82 for the six months ended June 30, 2019 and $1.78 for the six months ended June 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 six months ended June 30, 2019 , Entergy Corporation issued 1,181,800 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards. Entergy Corporation did not repurchase any of its common stock during the six months ended June 30, 2019 . Retained Earnings On July 26, 2019, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.91 per share, payable on September 3, 2019, to holders of record as of August 8, 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 June 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, April 1, 2019 ($43,246 ) ($520,372 ) $12,466 ($551,152 ) Other comprehensive income (loss) before reclassifications 99,359 — 15,834 115,193 Amounts reclassified from accumulated other comprehensive income (loss) (4,377 ) 11,496 (1,564 ) 5,555 Net other comprehensive income (loss) for the period 94,982 11,496 14,270 120,748 Ending balance, June 30, 2019 $51,736 ($508,876 ) $26,736 ($430,404 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 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, April 1, 2018 $50,194 ($605,491 ) ($6,201 ) ($561,498 ) Other comprehensive income (loss) before reclassifications (62,981 ) — (7,509 ) (70,490 ) Amounts reclassified from accumulated other comprehensive income (loss) (2,087 ) 15,565 4,868 18,346 Net other comprehensive income (loss) for the period (65,068 ) 15,565 (2,641 ) (52,144 ) Ending balance, June 30, 2018 ($14,874 ) ($589,926 ) ($8,842 ) ($613,642 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 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 127,670 — 29,373 157,043 Amounts reclassified from accumulated other comprehensive income (loss) (45,114 ) 23,046 (1,400 ) (23,468 ) Net other comprehensive income (loss) for the period 82,556 23,046 27,973 133,575 Ending balance, June 30, 2019 $51,736 ($508,876 ) $26,736 ($430,404 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 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 8,585 — (43,785 ) (35,200 ) Amounts reclassified from accumulated other comprehensive income (loss) 21,774 32,139 8,288 62,201 Net other comprehensive income (loss) for the period 30,359 32,139 (35,497 ) 27,001 Reclassification pursuant to ASU 2018-02 (7,756 ) (90,966 ) 114,227 15,505 Ending balance, June 30, 2018 ($14,874 ) ($589,926 ) ($8,842 ) ($613,642 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended June 30, 2019 and 2018: Pension and Other 2019 2018 (In Thousands) Beginning balance, April 1, ($7,122 ) ($56,950 ) Amounts reclassified from accumulated other (969 ) (501 ) Net other comprehensive income (loss) for the period (969 ) (501 ) Ending balance, June 30, ($8,091 ) ($57,451 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2019 and 2018: Pension and Other 2019 2018 (In Thousands) Beginning balance, January 1, ($6,153 ) ($46,400 ) Amounts reclassified from accumulated other (1,938 ) (1,002 ) Net other comprehensive income (loss) for the period (1,938 ) (1,002 ) Reclassification pursuant to ASU 2018-02 — (10,049 ) Ending balance, June 30, ($8,091 ) ($57,451 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended June 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 $5,589 $2,735 Competitive business operating revenues Interest rate swaps (48 ) (93 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 5,541 2,642 (1,164 ) (555 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $4,377 $2,087 Pension and other postretirement liabilities Amortization of prior-service credit $5,325 $5,424 (a) Amortization of loss (18,980 ) (24,808 ) (a) Settlement loss (918 ) (406 ) (a) Total amortization (14,573 ) (19,790 ) 3,077 4,225 Income taxes Total amortization (net of tax) ($11,496 ) ($15,565 ) Net unrealized investment gain (loss) Realized gain (loss) $2,475 ($7,702 ) Interest and investment income (911 ) 2,834 Income taxes Total realized investment gain (loss) (net of tax) $1,564 ($4,868 ) Total reclassifications for the period (net of tax) ($5,555 ) ($18,346 ) (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 six months ended June 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 $57,204 ($27,347 ) Competitive business operating revenues Interest rate swaps (97 ) (215 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 57,107 (27,562 ) (11,993 ) 5,788 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $45,114 ($21,774 ) Pension and other postretirement liabilities Amortization of prior-service credit $10,652 $10,850 (a) Amortization of loss (37,969 ) (49,760 ) (a) Settlement loss (2,055 ) (2,022 ) (a) Total amortization (29,372 ) (40,932 ) 6,326 8,793 Income taxes Total amortization (net of tax) ($23,046 ) ($32,139 ) Net unrealized investment gain (loss) Realized gain (loss) $2,216 ($13,114 ) Interest and investment income (816 ) 4,826 Income taxes Total realized investment gain (loss) (net of tax) $1,400 ($8,288 ) Total reclassifications for the period (net of tax) $23,468 ($62,201 ) (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 June 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 ) (1,256 ) (a) Total amortization 1,311 678 (342 ) (177 ) Income taxes Total amortization (net of tax) 969 501 Total reclassifications for the period (net of tax) $969 $501 (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 six months ended June 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 $3,674 $3,868 (a) Amortization of loss (1,052 ) (2,513 ) (a) Total amortization 2,622 1,355 (684 ) (353 ) Income taxes Total amortization (net of tax) 1,938 1,002 Total reclassifications for the period (net of tax) $1,938 $1,002 (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, Li

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	6 Months Ended
	Jun. 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 2023. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the six months ended June 30, 2019 was 4.05% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $150 $6 $3,344 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the 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 June 30, 2019 , Entergy Corporation had approximately $1,635 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2019 was 2.97% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2019 Letters of Credit Outstanding as of June 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.57% $— $— Entergy Arkansas September 2023 $150 million (c) 3.57% $— $— Entergy Louisiana September 2023 $350 million (c) 3.57% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.82% $— $— Entergy Mississippi May 2020 $35 million (d) 3.82% $— $— Entergy Mississippi May 2020 $10 million (d) 3.82% $— $— Entergy New Orleans November 2021 $25 million (c) 3.59% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.82% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 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 June 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $37.8 million Entergy Mississippi $40 million 0.70% $10.9 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $29.5 million (a) As of June 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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, 2019. 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 June 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 $36 Entergy Texas $200 $169 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 June 30, 2019 , $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2019 was 4.19% 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 June 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.40% $20.6 Entergy Louisiana River Bend VIE September 2021 $105 3.40% $87.5 Entergy Louisiana Waterford VIE September 2021 $105 3.40% $79.2 System Energy VIE September 2021 $120 3.40% $74.4 (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 June 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. (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 June 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,354,298 $18,126,143 Entergy Arkansas $3,527,146 $3,523,519 Entergy Louisiana $7,359,935 $7,892,133 Entergy Mississippi $1,619,420 $1,680,869 Entergy New Orleans $478,514 $511,691 Entergy Texas $1,664,936 $1,786,350 System Energy $590,646 $571,693 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $189 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 2023. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the six months ended June 30, 2019 was 4.05% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $150 $6 $3,344 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the 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 June 30, 2019 , Entergy Corporation had approximately $1,635 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2019 was 2.97% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2019 Letters of Credit Outstanding as of June 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.57% $— $— Entergy Arkansas September 2023 $150 million (c) 3.57% $— $— Entergy Louisiana September 2023 $350 million (c) 3.57% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.82% $— $— Entergy Mississippi May 2020 $35 million (d) 3.82% $— $— Entergy Mississippi May 2020 $10 million (d) 3.82% $— $— Entergy New Orleans November 2021 $25 million (c) 3.59% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.82% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 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 June 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $37.8 million Entergy Mississippi $40 million 0.70% $10.9 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $29.5 million (a) As of June 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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, 2019. 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 June 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 $36 Entergy Texas $200 $169 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 June 30, 2019 , $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2019 was 4.19% 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 June 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.40% $20.6 Entergy Louisiana River Bend VIE September 2021 $105 3.40% $87.5 Entergy Louisiana Waterford VIE September 2021 $105 3.40% $79.2 System Energy VIE September 2021 $120 3.40% $74.4 (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 June 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. (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 June 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,354,298 $18,126,143 Entergy Arkansas $3,527,146 $3,523,519 Entergy Louisiana $7,359,935 $7,892,133 Entergy Mississippi $1,619,420 $1,680,869 Entergy New Orleans $478,514 $511,691 Entergy Texas $1,664,936 $1,786,350 System Energy $590,646 $571,693 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $189 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 2023. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the six months ended June 30, 2019 was 4.05% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $150 $6 $3,344 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the 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 June 30, 2019 , Entergy Corporation had approximately $1,635 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2019 was 2.97% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2019 Letters of Credit Outstanding as of June 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.57% $— $— Entergy Arkansas September 2023 $150 million (c) 3.57% $— $— Entergy Louisiana September 2023 $350 million (c) 3.57% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.82% $— $— Entergy Mississippi May 2020 $35 million (d) 3.82% $— $— Entergy Mississippi May 2020 $10 million (d) 3.82% $— $— Entergy New Orleans November 2021 $25 million (c) 3.59% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.82% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 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 June 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $37.8 million Entergy Mississippi $40 million 0.70% $10.9 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $29.5 million (a) As of June 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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, 2019. 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 June 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 $36 Entergy Texas $200 $169 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 June 30, 2019 , $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2019 was 4.19% 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 June 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.40% $20.6 Entergy Louisiana River Bend VIE September 2021 $105 3.40% $87.5 Entergy Louisiana Waterford VIE September 2021 $105 3.40% $79.2 System Energy VIE September 2021 $120 3.40% $74.4 (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 June 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. (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 June 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,354,298 $18,126,143 Entergy Arkansas $3,527,146 $3,523,519 Entergy Louisiana $7,359,935 $7,892,133 Entergy Mississippi $1,619,420 $1,680,869 Entergy New Orleans $478,514 $511,691 Entergy Texas $1,664,936 $1,786,350 System Energy $590,646 $571,693 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $189 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 2023. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the six months ended June 30, 2019 was 4.05% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $150 $6 $3,344 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the 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 June 30, 2019 , Entergy Corporation had approximately $1,635 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2019 was 2.97% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2019 Letters of Credit Outstanding as of June 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.57% $— $— Entergy Arkansas September 2023 $150 million (c) 3.57% $— $— Entergy Louisiana September 2023 $350 million (c) 3.57% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.82% $— $— Entergy Mississippi May 2020 $35 million (d) 3.82% $— $— Entergy Mississippi May 2020 $10 million (d) 3.82% $— $— Entergy New Orleans November 2021 $25 million (c) 3.59% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.82% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 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 June 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $37.8 million Entergy Mississippi $40 million 0.70% $10.9 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $29.5 million (a) As of June 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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, 2019. 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 June 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 $36 Entergy Texas $200 $169 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 June 30, 2019 , $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2019 was 4.19% 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 June 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.40% $20.6 Entergy Louisiana River Bend VIE September 2021 $105 3.40% $87.5 Entergy Louisiana Waterford VIE September 2021 $105 3.40% $79.2 System Energy VIE September 2021 $120 3.40% $74.4 (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 June 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. (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 June 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,354,298 $18,126,143 Entergy Arkansas $3,527,146 $3,523,519 Entergy Louisiana $7,359,935 $7,892,133 Entergy Mississippi $1,619,420 $1,680,869 Entergy New Orleans $478,514 $511,691 Entergy Texas $1,664,936 $1,786,350 System Energy $590,646 $571,693 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $189 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 2023. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the six months ended June 30, 2019 was 4.05% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $150 $6 $3,344 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the 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 June 30, 2019 , Entergy Corporation had approximately $1,635 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2019 was 2.97% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2019 Letters of Credit Outstanding as of June 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.57% $— $— Entergy Arkansas September 2023 $150 million (c) 3.57% $— $— Entergy Louisiana September 2023 $350 million (c) 3.57% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.82% $— $— Entergy Mississippi May 2020 $35 million (d) 3.82% $— $— Entergy Mississippi May 2020 $10 million (d) 3.82% $— $— Entergy New Orleans November 2021 $25 million (c) 3.59% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.82% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 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 June 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $37.8 million Entergy Mississippi $40 million 0.70% $10.9 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $29.5 million (a) As of June 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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, 2019. 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 June 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 $36 Entergy Texas $200 $169 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 June 30, 2019 , $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2019 was 4.19% 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 June 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.40% $20.6 Entergy Louisiana River Bend VIE September 2021 $105 3.40% $87.5 Entergy Louisiana Waterford VIE September 2021 $105 3.40% $79.2 System Energy VIE September 2021 $120 3.40% $74.4 (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 June 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. (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 June 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,354,298 $18,126,143 Entergy Arkansas $3,527,146 $3,523,519 Entergy Louisiana $7,359,935 $7,892,133 Entergy Mississippi $1,619,420 $1,680,869 Entergy New Orleans $478,514 $511,691 Entergy Texas $1,664,936 $1,786,350 System Energy $590,646 $571,693 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $189 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 2023. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the six months ended June 30, 2019 was 4.05% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $150 $6 $3,344 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the 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 June 30, 2019 , Entergy Corporation had approximately $1,635 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2019 was 2.97% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2019 Letters of Credit Outstanding as of June 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.57% $— $— Entergy Arkansas September 2023 $150 million (c) 3.57% $— $— Entergy Louisiana September 2023 $350 million (c) 3.57% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.82% $— $— Entergy Mississippi May 2020 $35 million (d) 3.82% $— $— Entergy Mississippi May 2020 $10 million (d) 3.82% $— $— Entergy New Orleans November 2021 $25 million (c) 3.59% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.82% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 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 June 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $37.8 million Entergy Mississippi $40 million 0.70% $10.9 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $29.5 million (a) As of June 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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, 2019. 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 June 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 $36 Entergy Texas $200 $169 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 June 30, 2019 , $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2019 was 4.19% 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 June 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.40% $20.6 Entergy Louisiana River Bend VIE September 2021 $105 3.40% $87.5 Entergy Louisiana Waterford VIE September 2021 $105 3.40% $79.2 System Energy VIE September 2021 $120 3.40% $74.4 (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 June 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. (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 June 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,354,298 $18,126,143 Entergy Arkansas $3,527,146 $3,523,519 Entergy Louisiana $7,359,935 $7,892,133 Entergy Mississippi $1,619,420 $1,680,869 Entergy New Orleans $478,514 $511,691 Entergy Texas $1,664,936 $1,786,350 System Energy $590,646 $571,693 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $189 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 2023. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the six months ended June 30, 2019 was 4.05% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $150 $6 $3,344 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the 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 June 30, 2019 , Entergy Corporation had approximately $1,635 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2019 was 2.97% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2019 Letters of Credit Outstanding as of June 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.57% $— $— Entergy Arkansas September 2023 $150 million (c) 3.57% $— $— Entergy Louisiana September 2023 $350 million (c) 3.57% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.82% $— $— Entergy Mississippi May 2020 $35 million (d) 3.82% $— $— Entergy Mississippi May 2020 $10 million (d) 3.82% $— $— Entergy New Orleans November 2021 $25 million (c) 3.59% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.82% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 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 June 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $37.8 million Entergy Mississippi $40 million 0.70% $10.9 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $29.5 million (a) As of June 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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, 2019. 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 June 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 $36 Entergy Texas $200 $169 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 June 30, 2019 , $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2019 was 4.19% 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 June 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.40% $20.6 Entergy Louisiana River Bend VIE September 2021 $105 3.40% $87.5 Entergy Louisiana Waterford VIE September 2021 $105 3.40% $79.2 System Energy VIE September 2021 $120 3.40% $74.4 (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 June 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. (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 June 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,354,298 $18,126,143 Entergy Arkansas $3,527,146 $3,523,519 Entergy Louisiana $7,359,935 $7,892,133 Entergy Mississippi $1,619,420 $1,680,869 Entergy New Orleans $478,514 $511,691 Entergy Texas $1,664,936 $1,786,350 System Energy $590,646 $571,693 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $189 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	6 Months Ended
	Jun. 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 June 30, 2019 , there were options on 2,912,294 shares of common stock outstanding with a weighted-average exercise price of $78.64 . The intrinsic value, which has no effect on net income, of the outstanding stock options is calculated by the positive difference between the weighted average exercise price of the stock options granted and Entergy Corporation’s common stock price as of June 30, 2019 . The aggregate intrinsic value of the stock options outstanding as of June 30, 2019 was $70.8 million . The following table includes financial information for outstanding stock options for the three months ended June 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $1.0 $1.1 Tax benefit recognized in Entergy’s net income $0.3 $0.3 Compensation cost capitalized as part of fixed assets and materials and supplies $0.3 $0.2 The following table includes financial information for outstanding stock options for the six months ended June 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $2.0 $2.2 Tax benefit recognized in Entergy’s net income $0.5 $0.6 Compensation cost capitalized as part of fixed assets and materials and supplies $0.6 $0.4 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 June 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $8.4 $8.7 Tax benefit recognized in Entergy’s net income $2.2 $2.2 Compensation cost capitalized as part of fixed assets and materials and supplies $2.9 $2.5 The following table includes financial information for other outstanding equity awards for the six months ended June 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $17.2 $17.5 Tax benefit recognized in Entergy’s net income $4.4 $4.4 Compensation cost capitalized as part of fixed assets and materials and supplies $5.8 $4.8

Retirement And Other Postretire

Retirement And Other Postretirement Benefits	6 Months Ended
	Jun. 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 second quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,606 $38,752 Interest cost on projected benefit obligation 73,912 66,854 Expected return on assets (103,859 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 58,420 68,526 Settlement charges 162 — Net pension costs $62,241 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $67,213 $77,504 Interest cost on projected benefit obligation 147,853 133,708 Expected return on assets (207,743 ) (221,070 ) Amortization of prior service cost — 198 Amortization of net loss 116,838 137,052 Settlement charges 1,299 — Net pension costs $125,460 $127,392 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second 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 $5,261 $7,284 $1,629 $569 $1,350 $1,550 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,874 3,612 3,363 Expected return on assets (20,176 ) (22,652 ) (5,968 ) (2,697 ) (5,862 ) (4,677 ) Amortization of net loss 11,841 11,643 3,105 1,530 2,334 2,850 Net pension cost $11,101 $12,157 $2,834 $1,276 $1,434 $3,086 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 six months ended June 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 $10,522 $14,568 $3,258 $1,138 $2,700 $3,100 Interest cost on projected benefit obligation 28,350 31,764 8,136 3,748 7,224 6,727 Expected return on assets (40,352 ) (45,304 ) (11,936 ) (5,393 ) (11,724 ) (9,354 ) Amortization of net loss 23,682 23,286 6,209 3,059 4,668 5,700 Net pension cost $22,202 $24,314 $5,667 $2,552 $2,868 $6,173 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $12,378 $16,892 $3,644 $1,346 $3,178 $3,552 Interest cost on projected benefit obligation 26,008 29,880 7,538 3,626 6,696 6,454 Expected return on assets (43,702 ) (49,618 ) (13,004 ) (5,986 ) (13,046 ) (9,982 ) Amortization of net loss 26,824 28,900 7,220 3,908 5,252 7,430 Net pension cost $21,508 $26,054 $5,398 $2,894 $2,080 $7,454 Non-Qualified Net Pension Cost Entergy recognized $7.6 million and $6.6 million in pension cost for its non-qualified pension plans in the second quarters of 2019 and 2018 , respectively. Reflected in the pension cost for non-qualified pension plans in the second quarters of 2019 and 2018 were settlement charges of $3.7 million and $2.4 million , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $11.6 million and $15.5 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the six months ended June 30, 2019 and 2018 were settlement charges of $3.7 million and $6.8 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 second quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $71 $41 $113 $6 $122 2018 $122 $46 $77 $21 $270 Reflected in Entergy Mississippi’s non-qualified pension costs in the second quarter of 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 in the second quarter of 2018 were settlement charges of $10 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs in the second quarter of 2018 were settlement charges of $139 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 six months ended June 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $144 $84 $188 $11 $246 2018 $254 $96 $157 $42 $407 Reflected in Entergy Mississippi’s non-qualified pension costs for the six months ended June 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 six months ended June 30, 2018 were settlement charges of $22 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the six months ended June 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 Entergy’s other postretirement benefit cost, including amounts capitalized, for the second 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, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $9,350 $13,564 Interest cost on accumulated postretirement benefit obligation (APBO) 23,950 25,362 Expected return on assets (19,124 ) (20,746 ) Amortization of prior service credit (17,688 ) (18,502 ) Amortization of net loss 716 6,864 Net other postretirement benefit cost (income) ($2,796 ) $6,542 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for second 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, including amounts capitalized, for their employees for the six months ended June 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 $1,182 $2,320 $524 $184 $472 $486 Interest cost on APBO 3,614 5,332 1,340 790 1,708 952 Expected return on assets (7,982 ) — (2,398 ) (2,474 ) (4,552 ) (1,394 ) Amortization of prior service credit (2,476 ) (3,674 ) (878 ) (342 ) (1,122 ) (726 ) Amortization of net (gain) loss 288 (348 ) 362 116 242 178 Net other postretirement benefit cost (income) ($5,374 ) $3,630 ($1,050 ) ($1,726 ) ($3,252 ) ($504 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,586 $3,112 $642 $258 $660 $612 Interest cost on APBO 3,994 5,578 1,366 834 1,878 1,000 Expected return on assets (8,684 ) — (2,606 ) (2,626 ) (4,892 ) (1,566 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of net loss 578 776 754 68 412 466 Net other postretirement benefit cost (income) ($5,082 ) $5,598 ($756 ) ($1,838 ) ($3,100 ) ($244 ) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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) (18,736 ) 308 (552 ) (18,980 ) Settlement loss (162 ) — (756 ) (918 ) ($18,898 ) $5,683 ($1,358 ) ($14,573 ) 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 ) $5,594 ($71 ) $5,424 Amortization of net loss (21,957 ) (1,933 ) (918 ) (24,808 ) Settlement loss — — (406 ) (406 ) ($22,056 ) $3,661 ($1,395 ) ($19,790 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (387 ) (2 ) (1,256 ) ($867 ) $1,547 ($2 ) $678 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,750 ($98 ) $10,652 Amortization of net gain (loss) (37,470 ) 615 (1,114 ) (37,969 ) Settlement loss (1,299 ) — (756 ) (2,055 ) ($38,769 ) $11,365 ($1,968 ) ($29,372 ) Entergy Louisiana Amortization of prior service credit $— $3,674 $— $3,674 Amortization of net gain (loss) (1,397 ) 348 (3 ) (1,052 ) ($1,397 ) $4,022 ($3 ) $2,622 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($198 ) $11,189 ($141 ) $10,850 Amortization of net loss (43,914 ) (3,865 ) (1,981 ) (49,760 ) Settlement loss — — (2,022 ) (2,022 ) ($44,112 ) $7,324 ($4,144 ) ($40,932 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of net loss (1,734 ) (775 ) (4 ) (2,513 ) ($1,734 ) $3,093 ($4 ) $1,355 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019. As of June 30, 2019 , Entergy had contributed $65.5 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 June 2019 $9,338 $10,093 $2,671 $674 $739 $2,944 Remaining estimated pension contributions to be made in 2019 $17,774 $16,358 $5,030 $1,126 $906 $5,341
Entergy Arkansas [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,606 $38,752 Interest cost on projected benefit obligation 73,912 66,854 Expected return on assets (103,859 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 58,420 68,526 Settlement charges 162 — Net pension costs $62,241 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $67,213 $77,504 Interest cost on projected benefit obligation 147,853 133,708 Expected return on assets (207,743 ) (221,070 ) Amortization of prior service cost — 198 Amortization of net loss 116,838 137,052 Settlement charges 1,299 — Net pension costs $125,460 $127,392 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second 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 $5,261 $7,284 $1,629 $569 $1,350 $1,550 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,874 3,612 3,363 Expected return on assets (20,176 ) (22,652 ) (5,968 ) (2,697 ) (5,862 ) (4,677 ) Amortization of net loss 11,841 11,643 3,105 1,530 2,334 2,850 Net pension cost $11,101 $12,157 $2,834 $1,276 $1,434 $3,086 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 six months ended June 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 $10,522 $14,568 $3,258 $1,138 $2,700 $3,100 Interest cost on projected benefit obligation 28,350 31,764 8,136 3,748 7,224 6,727 Expected return on assets (40,352 ) (45,304 ) (11,936 ) (5,393 ) (11,724 ) (9,354 ) Amortization of net loss 23,682 23,286 6,209 3,059 4,668 5,700 Net pension cost $22,202 $24,314 $5,667 $2,552 $2,868 $6,173 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $12,378 $16,892 $3,644 $1,346 $3,178 $3,552 Interest cost on projected benefit obligation 26,008 29,880 7,538 3,626 6,696 6,454 Expected return on assets (43,702 ) (49,618 ) (13,004 ) (5,986 ) (13,046 ) (9,982 ) Amortization of net loss 26,824 28,900 7,220 3,908 5,252 7,430 Net pension cost $21,508 $26,054 $5,398 $2,894 $2,080 $7,454 Non-Qualified Net Pension Cost Entergy recognized $7.6 million and $6.6 million in pension cost for its non-qualified pension plans in the second quarters of 2019 and 2018 , respectively. Reflected in the pension cost for non-qualified pension plans in the second quarters of 2019 and 2018 were settlement charges of $3.7 million and $2.4 million , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $11.6 million and $15.5 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the six months ended June 30, 2019 and 2018 were settlement charges of $3.7 million and $6.8 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 second quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $71 $41 $113 $6 $122 2018 $122 $46 $77 $21 $270 Reflected in Entergy Mississippi’s non-qualified pension costs in the second quarter of 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 in the second quarter of 2018 were settlement charges of $10 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs in the second quarter of 2018 were settlement charges of $139 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 six months ended June 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $144 $84 $188 $11 $246 2018 $254 $96 $157 $42 $407 Reflected in Entergy Mississippi’s non-qualified pension costs for the six months ended June 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 six months ended June 30, 2018 were settlement charges of $22 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the six months ended June 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 Entergy’s other postretirement benefit cost, including amounts capitalized, for the second 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, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $9,350 $13,564 Interest cost on accumulated postretirement benefit obligation (APBO) 23,950 25,362 Expected return on assets (19,124 ) (20,746 ) Amortization of prior service credit (17,688 ) (18,502 ) Amortization of net loss 716 6,864 Net other postretirement benefit cost (income) ($2,796 ) $6,542 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for second 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, including amounts capitalized, for their employees for the six months ended June 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 $1,182 $2,320 $524 $184 $472 $486 Interest cost on APBO 3,614 5,332 1,340 790 1,708 952 Expected return on assets (7,982 ) — (2,398 ) (2,474 ) (4,552 ) (1,394 ) Amortization of prior service credit (2,476 ) (3,674 ) (878 ) (342 ) (1,122 ) (726 ) Amortization of net (gain) loss 288 (348 ) 362 116 242 178 Net other postretirement benefit cost (income) ($5,374 ) $3,630 ($1,050 ) ($1,726 ) ($3,252 ) ($504 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,586 $3,112 $642 $258 $660 $612 Interest cost on APBO 3,994 5,578 1,366 834 1,878 1,000 Expected return on assets (8,684 ) — (2,606 ) (2,626 ) (4,892 ) (1,566 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of net loss 578 776 754 68 412 466 Net other postretirement benefit cost (income) ($5,082 ) $5,598 ($756 ) ($1,838 ) ($3,100 ) ($244 ) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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) (18,736 ) 308 (552 ) (18,980 ) Settlement loss (162 ) — (756 ) (918 ) ($18,898 ) $5,683 ($1,358 ) ($14,573 ) 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 ) $5,594 ($71 ) $5,424 Amortization of net loss (21,957 ) (1,933 ) (918 ) (24,808 ) Settlement loss — — (406 ) (406 ) ($22,056 ) $3,661 ($1,395 ) ($19,790 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (387 ) (2 ) (1,256 ) ($867 ) $1,547 ($2 ) $678 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,750 ($98 ) $10,652 Amortization of net gain (loss) (37,470 ) 615 (1,114 ) (37,969 ) Settlement loss (1,299 ) — (756 ) (2,055 ) ($38,769 ) $11,365 ($1,968 ) ($29,372 ) Entergy Louisiana Amortization of prior service credit $— $3,674 $— $3,674 Amortization of net gain (loss) (1,397 ) 348 (3 ) (1,052 ) ($1,397 ) $4,022 ($3 ) $2,622 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($198 ) $11,189 ($141 ) $10,850 Amortization of net loss (43,914 ) (3,865 ) (1,981 ) (49,760 ) Settlement loss — — (2,022 ) (2,022 ) ($44,112 ) $7,324 ($4,144 ) ($40,932 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of net loss (1,734 ) (775 ) (4 ) (2,513 ) ($1,734 ) $3,093 ($4 ) $1,355 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019. As of June 30, 2019 , Entergy had contributed $65.5 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 June 2019 $9,338 $10,093 $2,671 $674 $739 $2,944 Remaining estimated pension contributions to be made in 2019 $17,774 $16,358 $5,030 $1,126 $906 $5,341
Entergy Louisiana [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,606 $38,752 Interest cost on projected benefit obligation 73,912 66,854 Expected return on assets (103,859 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 58,420 68,526 Settlement charges 162 — Net pension costs $62,241 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $67,213 $77,504 Interest cost on projected benefit obligation 147,853 133,708 Expected return on assets (207,743 ) (221,070 ) Amortization of prior service cost — 198 Amortization of net loss 116,838 137,052 Settlement charges 1,299 — Net pension costs $125,460 $127,392 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second 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 $5,261 $7,284 $1,629 $569 $1,350 $1,550 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,874 3,612 3,363 Expected return on assets (20,176 ) (22,652 ) (5,968 ) (2,697 ) (5,862 ) (4,677 ) Amortization of net loss 11,841 11,643 3,105 1,530 2,334 2,850 Net pension cost $11,101 $12,157 $2,834 $1,276 $1,434 $3,086 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 six months ended June 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 $10,522 $14,568 $3,258 $1,138 $2,700 $3,100 Interest cost on projected benefit obligation 28,350 31,764 8,136 3,748 7,224 6,727 Expected return on assets (40,352 ) (45,304 ) (11,936 ) (5,393 ) (11,724 ) (9,354 ) Amortization of net loss 23,682 23,286 6,209 3,059 4,668 5,700 Net pension cost $22,202 $24,314 $5,667 $2,552 $2,868 $6,173 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $12,378 $16,892 $3,644 $1,346 $3,178 $3,552 Interest cost on projected benefit obligation 26,008 29,880 7,538 3,626 6,696 6,454 Expected return on assets (43,702 ) (49,618 ) (13,004 ) (5,986 ) (13,046 ) (9,982 ) Amortization of net loss 26,824 28,900 7,220 3,908 5,252 7,430 Net pension cost $21,508 $26,054 $5,398 $2,894 $2,080 $7,454 Non-Qualified Net Pension Cost Entergy recognized $7.6 million and $6.6 million in pension cost for its non-qualified pension plans in the second quarters of 2019 and 2018 , respectively. Reflected in the pension cost for non-qualified pension plans in the second quarters of 2019 and 2018 were settlement charges of $3.7 million and $2.4 million , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $11.6 million and $15.5 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the six months ended June 30, 2019 and 2018 were settlement charges of $3.7 million and $6.8 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 second quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $71 $41 $113 $6 $122 2018 $122 $46 $77 $21 $270 Reflected in Entergy Mississippi’s non-qualified pension costs in the second quarter of 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 in the second quarter of 2018 were settlement charges of $10 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs in the second quarter of 2018 were settlement charges of $139 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 six months ended June 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $144 $84 $188 $11 $246 2018 $254 $96 $157 $42 $407 Reflected in Entergy Mississippi’s non-qualified pension costs for the six months ended June 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 six months ended June 30, 2018 were settlement charges of $22 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the six months ended June 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 Entergy’s other postretirement benefit cost, including amounts capitalized, for the second 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, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $9,350 $13,564 Interest cost on accumulated postretirement benefit obligation (APBO) 23,950 25,362 Expected return on assets (19,124 ) (20,746 ) Amortization of prior service credit (17,688 ) (18,502 ) Amortization of net loss 716 6,864 Net other postretirement benefit cost (income) ($2,796 ) $6,542 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for second 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, including amounts capitalized, for their employees for the six months ended June 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 $1,182 $2,320 $524 $184 $472 $486 Interest cost on APBO 3,614 5,332 1,340 790 1,708 952 Expected return on assets (7,982 ) — (2,398 ) (2,474 ) (4,552 ) (1,394 ) Amortization of prior service credit (2,476 ) (3,674 ) (878 ) (342 ) (1,122 ) (726 ) Amortization of net (gain) loss 288 (348 ) 362 116 242 178 Net other postretirement benefit cost (income) ($5,374 ) $3,630 ($1,050 ) ($1,726 ) ($3,252 ) ($504 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,586 $3,112 $642 $258 $660 $612 Interest cost on APBO 3,994 5,578 1,366 834 1,878 1,000 Expected return on assets (8,684 ) — (2,606 ) (2,626 ) (4,892 ) (1,566 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of net loss 578 776 754 68 412 466 Net other postretirement benefit cost (income) ($5,082 ) $5,598 ($756 ) ($1,838 ) ($3,100 ) ($244 ) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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) (18,736 ) 308 (552 ) (18,980 ) Settlement loss (162 ) — (756 ) (918 ) ($18,898 ) $5,683 ($1,358 ) ($14,573 ) 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 ) $5,594 ($71 ) $5,424 Amortization of net loss (21,957 ) (1,933 ) (918 ) (24,808 ) Settlement loss — — (406 ) (406 ) ($22,056 ) $3,661 ($1,395 ) ($19,790 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (387 ) (2 ) (1,256 ) ($867 ) $1,547 ($2 ) $678 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,750 ($98 ) $10,652 Amortization of net gain (loss) (37,470 ) 615 (1,114 ) (37,969 ) Settlement loss (1,299 ) — (756 ) (2,055 ) ($38,769 ) $11,365 ($1,968 ) ($29,372 ) Entergy Louisiana Amortization of prior service credit $— $3,674 $— $3,674 Amortization of net gain (loss) (1,397 ) 348 (3 ) (1,052 ) ($1,397 ) $4,022 ($3 ) $2,622 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($198 ) $11,189 ($141 ) $10,850 Amortization of net loss (43,914 ) (3,865 ) (1,981 ) (49,760 ) Settlement loss — — (2,022 ) (2,022 ) ($44,112 ) $7,324 ($4,144 ) ($40,932 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of net loss (1,734 ) (775 ) (4 ) (2,513 ) ($1,734 ) $3,093 ($4 ) $1,355 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019. As of June 30, 2019 , Entergy had contributed $65.5 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 June 2019 $9,338 $10,093 $2,671 $674 $739 $2,944 Remaining estimated pension contributions to be made in 2019 $17,774 $16,358 $5,030 $1,126 $906 $5,341
Entergy Mississippi [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,606 $38,752 Interest cost on projected benefit obligation 73,912 66,854 Expected return on assets (103,859 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 58,420 68,526 Settlement charges 162 — Net pension costs $62,241 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $67,213 $77,504 Interest cost on projected benefit obligation 147,853 133,708 Expected return on assets (207,743 ) (221,070 ) Amortization of prior service cost — 198 Amortization of net loss 116,838 137,052 Settlement charges 1,299 — Net pension costs $125,460 $127,392 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second 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 $5,261 $7,284 $1,629 $569 $1,350 $1,550 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,874 3,612 3,363 Expected return on assets (20,176 ) (22,652 ) (5,968 ) (2,697 ) (5,862 ) (4,677 ) Amortization of net loss 11,841 11,643 3,105 1,530 2,334 2,850 Net pension cost $11,101 $12,157 $2,834 $1,276 $1,434 $3,086 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 six months ended June 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 $10,522 $14,568 $3,258 $1,138 $2,700 $3,100 Interest cost on projected benefit obligation 28,350 31,764 8,136 3,748 7,224 6,727 Expected return on assets (40,352 ) (45,304 ) (11,936 ) (5,393 ) (11,724 ) (9,354 ) Amortization of net loss 23,682 23,286 6,209 3,059 4,668 5,700 Net pension cost $22,202 $24,314 $5,667 $2,552 $2,868 $6,173 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $12,378 $16,892 $3,644 $1,346 $3,178 $3,552 Interest cost on projected benefit obligation 26,008 29,880 7,538 3,626 6,696 6,454 Expected return on assets (43,702 ) (49,618 ) (13,004 ) (5,986 ) (13,046 ) (9,982 ) Amortization of net loss 26,824 28,900 7,220 3,908 5,252 7,430 Net pension cost $21,508 $26,054 $5,398 $2,894 $2,080 $7,454 Non-Qualified Net Pension Cost Entergy recognized $7.6 million and $6.6 million in pension cost for its non-qualified pension plans in the second quarters of 2019 and 2018 , respectively. Reflected in the pension cost for non-qualified pension plans in the second quarters of 2019 and 2018 were settlement charges of $3.7 million and $2.4 million , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $11.6 million and $15.5 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the six months ended June 30, 2019 and 2018 were settlement charges of $3.7 million and $6.8 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 second quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $71 $41 $113 $6 $122 2018 $122 $46 $77 $21 $270 Reflected in Entergy Mississippi’s non-qualified pension costs in the second quarter of 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 in the second quarter of 2018 were settlement charges of $10 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs in the second quarter of 2018 were settlement charges of $139 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 six months ended June 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $144 $84 $188 $11 $246 2018 $254 $96 $157 $42 $407 Reflected in Entergy Mississippi’s non-qualified pension costs for the six months ended June 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 six months ended June 30, 2018 were settlement charges of $22 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the six months ended June 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 Entergy’s other postretirement benefit cost, including amounts capitalized, for the second 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, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $9,350 $13,564 Interest cost on accumulated postretirement benefit obligation (APBO) 23,950 25,362 Expected return on assets (19,124 ) (20,746 ) Amortization of prior service credit (17,688 ) (18,502 ) Amortization of net loss 716 6,864 Net other postretirement benefit cost (income) ($2,796 ) $6,542 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for second 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, including amounts capitalized, for their employees for the six months ended June 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 $1,182 $2,320 $524 $184 $472 $486 Interest cost on APBO 3,614 5,332 1,340 790 1,708 952 Expected return on assets (7,982 ) — (2,398 ) (2,474 ) (4,552 ) (1,394 ) Amortization of prior service credit (2,476 ) (3,674 ) (878 ) (342 ) (1,122 ) (726 ) Amortization of net (gain) loss 288 (348 ) 362 116 242 178 Net other postretirement benefit cost (income) ($5,374 ) $3,630 ($1,050 ) ($1,726 ) ($3,252 ) ($504 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,586 $3,112 $642 $258 $660 $612 Interest cost on APBO 3,994 5,578 1,366 834 1,878 1,000 Expected return on assets (8,684 ) — (2,606 ) (2,626 ) (4,892 ) (1,566 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of net loss 578 776 754 68 412 466 Net other postretirement benefit cost (income) ($5,082 ) $5,598 ($756 ) ($1,838 ) ($3,100 ) ($244 ) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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) (18,736 ) 308 (552 ) (18,980 ) Settlement loss (162 ) — (756 ) (918 ) ($18,898 ) $5,683 ($1,358 ) ($14,573 ) 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 ) $5,594 ($71 ) $5,424 Amortization of net loss (21,957 ) (1,933 ) (918 ) (24,808 ) Settlement loss — — (406 ) (406 ) ($22,056 ) $3,661 ($1,395 ) ($19,790 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (387 ) (2 ) (1,256 ) ($867 ) $1,547 ($2 ) $678 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,750 ($98 ) $10,652 Amortization of net gain (loss) (37,470 ) 615 (1,114 ) (37,969 ) Settlement loss (1,299 ) — (756 ) (2,055 ) ($38,769 ) $11,365 ($1,968 ) ($29,372 ) Entergy Louisiana Amortization of prior service credit $— $3,674 $— $3,674 Amortization of net gain (loss) (1,397 ) 348 (3 ) (1,052 ) ($1,397 ) $4,022 ($3 ) $2,622 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($198 ) $11,189 ($141 ) $10,850 Amortization of net loss (43,914 ) (3,865 ) (1,981 ) (49,760 ) Settlement loss — — (2,022 ) (2,022 ) ($44,112 ) $7,324 ($4,144 ) ($40,932 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of net loss (1,734 ) (775 ) (4 ) (2,513 ) ($1,734 ) $3,093 ($4 ) $1,355 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019. As of June 30, 2019 , Entergy had contributed $65.5 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 June 2019 $9,338 $10,093 $2,671 $674 $739 $2,944 Remaining estimated pension contributions to be made in 2019 $17,774 $16,358 $5,030 $1,126 $906 $5,341
Entergy New Orleans [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,606 $38,752 Interest cost on projected benefit obligation 73,912 66,854 Expected return on assets (103,859 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 58,420 68,526 Settlement charges 162 — Net pension costs $62,241 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $67,213 $77,504 Interest cost on projected benefit obligation 147,853 133,708 Expected return on assets (207,743 ) (221,070 ) Amortization of prior service cost — 198 Amortization of net loss 116,838 137,052 Settlement charges 1,299 — Net pension costs $125,460 $127,392 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second 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 $5,261 $7,284 $1,629 $569 $1,350 $1,550 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,874 3,612 3,363 Expected return on assets (20,176 ) (22,652 ) (5,968 ) (2,697 ) (5,862 ) (4,677 ) Amortization of net loss 11,841 11,643 3,105 1,530 2,334 2,850 Net pension cost $11,101 $12,157 $2,834 $1,276 $1,434 $3,086 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 six months ended June 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 $10,522 $14,568 $3,258 $1,138 $2,700 $3,100 Interest cost on projected benefit obligation 28,350 31,764 8,136 3,748 7,224 6,727 Expected return on assets (40,352 ) (45,304 ) (11,936 ) (5,393 ) (11,724 ) (9,354 ) Amortization of net loss 23,682 23,286 6,209 3,059 4,668 5,700 Net pension cost $22,202 $24,314 $5,667 $2,552 $2,868 $6,173 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $12,378 $16,892 $3,644 $1,346 $3,178 $3,552 Interest cost on projected benefit obligation 26,008 29,880 7,538 3,626 6,696 6,454 Expected return on assets (43,702 ) (49,618 ) (13,004 ) (5,986 ) (13,046 ) (9,982 ) Amortization of net loss 26,824 28,900 7,220 3,908 5,252 7,430 Net pension cost $21,508 $26,054 $5,398 $2,894 $2,080 $7,454 Non-Qualified Net Pension Cost Entergy recognized $7.6 million and $6.6 million in pension cost for its non-qualified pension plans in the second quarters of 2019 and 2018 , respectively. Reflected in the pension cost for non-qualified pension plans in the second quarters of 2019 and 2018 were settlement charges of $3.7 million and $2.4 million , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $11.6 million and $15.5 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the six months ended June 30, 2019 and 2018 were settlement charges of $3.7 million and $6.8 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 second quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $71 $41 $113 $6 $122 2018 $122 $46 $77 $21 $270 Reflected in Entergy Mississippi’s non-qualified pension costs in the second quarter of 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 in the second quarter of 2018 were settlement charges of $10 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs in the second quarter of 2018 were settlement charges of $139 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 six months ended June 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $144 $84 $188 $11 $246 2018 $254 $96 $157 $42 $407 Reflected in Entergy Mississippi’s non-qualified pension costs for the six months ended June 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 six months ended June 30, 2018 were settlement charges of $22 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the six months ended June 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 Entergy’s other postretirement benefit cost, including amounts capitalized, for the second 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, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $9,350 $13,564 Interest cost on accumulated postretirement benefit obligation (APBO) 23,950 25,362 Expected return on assets (19,124 ) (20,746 ) Amortization of prior service credit (17,688 ) (18,502 ) Amortization of net loss 716 6,864 Net other postretirement benefit cost (income) ($2,796 ) $6,542 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for second 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, including amounts capitalized, for their employees for the six months ended June 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 $1,182 $2,320 $524 $184 $472 $486 Interest cost on APBO 3,614 5,332 1,340 790 1,708 952 Expected return on assets (7,982 ) — (2,398 ) (2,474 ) (4,552 ) (1,394 ) Amortization of prior service credit (2,476 ) (3,674 ) (878 ) (342 ) (1,122 ) (726 ) Amortization of net (gain) loss 288 (348 ) 362 116 242 178 Net other postretirement benefit cost (income) ($5,374 ) $3,630 ($1,050 ) ($1,726 ) ($3,252 ) ($504 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,586 $3,112 $642 $258 $660 $612 Interest cost on APBO 3,994 5,578 1,366 834 1,878 1,000 Expected return on assets (8,684 ) — (2,606 ) (2,626 ) (4,892 ) (1,566 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of net loss 578 776 754 68 412 466 Net other postretirement benefit cost (income) ($5,082 ) $5,598 ($756 ) ($1,838 ) ($3,100 ) ($244 ) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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) (18,736 ) 308 (552 ) (18,980 ) Settlement loss (162 ) — (756 ) (918 ) ($18,898 ) $5,683 ($1,358 ) ($14,573 ) 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 ) $5,594 ($71 ) $5,424 Amortization of net loss (21,957 ) (1,933 ) (918 ) (24,808 ) Settlement loss — — (406 ) (406 ) ($22,056 ) $3,661 ($1,395 ) ($19,790 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (387 ) (2 ) (1,256 ) ($867 ) $1,547 ($2 ) $678 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,750 ($98 ) $10,652 Amortization of net gain (loss) (37,470 ) 615 (1,114 ) (37,969 ) Settlement loss (1,299 ) — (756 ) (2,055 ) ($38,769 ) $11,365 ($1,968 ) ($29,372 ) Entergy Louisiana Amortization of prior service credit $— $3,674 $— $3,674 Amortization of net gain (loss) (1,397 ) 348 (3 ) (1,052 ) ($1,397 ) $4,022 ($3 ) $2,622 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($198 ) $11,189 ($141 ) $10,850 Amortization of net loss (43,914 ) (3,865 ) (1,981 ) (49,760 ) Settlement loss — — (2,022 ) (2,022 ) ($44,112 ) $7,324 ($4,144 ) ($40,932 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of net loss (1,734 ) (775 ) (4 ) (2,513 ) ($1,734 ) $3,093 ($4 ) $1,355 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019. As of June 30, 2019 , Entergy had contributed $65.5 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 June 2019 $9,338 $10,093 $2,671 $674 $739 $2,944 Remaining estimated pension contributions to be made in 2019 $17,774 $16,358 $5,030 $1,126 $906 $5,341
Entergy Texas [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,606 $38,752 Interest cost on projected benefit obligation 73,912 66,854 Expected return on assets (103,859 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 58,420 68,526 Settlement charges 162 — Net pension costs $62,241 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $67,213 $77,504 Interest cost on projected benefit obligation 147,853 133,708 Expected return on assets (207,743 ) (221,070 ) Amortization of prior service cost — 198 Amortization of net loss 116,838 137,052 Settlement charges 1,299 — Net pension costs $125,460 $127,392 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second 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 $5,261 $7,284 $1,629 $569 $1,350 $1,550 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,874 3,612 3,363 Expected return on assets (20,176 ) (22,652 ) (5,968 ) (2,697 ) (5,862 ) (4,677 ) Amortization of net loss 11,841 11,643 3,105 1,530 2,334 2,850 Net pension cost $11,101 $12,157 $2,834 $1,276 $1,434 $3,086 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 six months ended June 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 $10,522 $14,568 $3,258 $1,138 $2,700 $3,100 Interest cost on projected benefit obligation 28,350 31,764 8,136 3,748 7,224 6,727 Expected return on assets (40,352 ) (45,304 ) (11,936 ) (5,393 ) (11,724 ) (9,354 ) Amortization of net loss 23,682 23,286 6,209 3,059 4,668 5,700 Net pension cost $22,202 $24,314 $5,667 $2,552 $2,868 $6,173 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $12,378 $16,892 $3,644 $1,346 $3,178 $3,552 Interest cost on projected benefit obligation 26,008 29,880 7,538 3,626 6,696 6,454 Expected return on assets (43,702 ) (49,618 ) (13,004 ) (5,986 ) (13,046 ) (9,982 ) Amortization of net loss 26,824 28,900 7,220 3,908 5,252 7,430 Net pension cost $21,508 $26,054 $5,398 $2,894 $2,080 $7,454 Non-Qualified Net Pension Cost Entergy recognized $7.6 million and $6.6 million in pension cost for its non-qualified pension plans in the second quarters of 2019 and 2018 , respectively. Reflected in the pension cost for non-qualified pension plans in the second quarters of 2019 and 2018 were settlement charges of $3.7 million and $2.4 million , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $11.6 million and $15.5 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the six months ended June 30, 2019 and 2018 were settlement charges of $3.7 million and $6.8 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 second quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $71 $41 $113 $6 $122 2018 $122 $46 $77 $21 $270 Reflected in Entergy Mississippi’s non-qualified pension costs in the second quarter of 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 in the second quarter of 2018 were settlement charges of $10 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs in the second quarter of 2018 were settlement charges of $139 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 six months ended June 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $144 $84 $188 $11 $246 2018 $254 $96 $157 $42 $407 Reflected in Entergy Mississippi’s non-qualified pension costs for the six months ended June 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 six months ended June 30, 2018 were settlement charges of $22 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the six months ended June 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 Entergy’s other postretirement benefit cost, including amounts capitalized, for the second 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, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $9,350 $13,564 Interest cost on accumulated postretirement benefit obligation (APBO) 23,950 25,362 Expected return on assets (19,124 ) (20,746 ) Amortization of prior service credit (17,688 ) (18,502 ) Amortization of net loss 716 6,864 Net other postretirement benefit cost (income) ($2,796 ) $6,542 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for second 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, including amounts capitalized, for their employees for the six months ended June 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 $1,182 $2,320 $524 $184 $472 $486 Interest cost on APBO 3,614 5,332 1,340 790 1,708 952 Expected return on assets (7,982 ) — (2,398 ) (2,474 ) (4,552 ) (1,394 ) Amortization of prior service credit (2,476 ) (3,674 ) (878 ) (342 ) (1,122 ) (726 ) Amortization of net (gain) loss 288 (348 ) 362 116 242 178 Net other postretirement benefit cost (income) ($5,374 ) $3,630 ($1,050 ) ($1,726 ) ($3,252 ) ($504 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,586 $3,112 $642 $258 $660 $612 Interest cost on APBO 3,994 5,578 1,366 834 1,878 1,000 Expected return on assets (8,684 ) — (2,606 ) (2,626 ) (4,892 ) (1,566 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of net loss 578 776 754 68 412 466 Net other postretirement benefit cost (income) ($5,082 ) $5,598 ($756 ) ($1,838 ) ($3,100 ) ($244 ) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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) (18,736 ) 308 (552 ) (18,980 ) Settlement loss (162 ) — (756 ) (918 ) ($18,898 ) $5,683 ($1,358 ) ($14,573 ) 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 ) $5,594 ($71 ) $5,424 Amortization of net loss (21,957 ) (1,933 ) (918 ) (24,808 ) Settlement loss — — (406 ) (406 ) ($22,056 ) $3,661 ($1,395 ) ($19,790 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (387 ) (2 ) (1,256 ) ($867 ) $1,547 ($2 ) $678 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,750 ($98 ) $10,652 Amortization of net gain (loss) (37,470 ) 615 (1,114 ) (37,969 ) Settlement loss (1,299 ) — (756 ) (2,055 ) ($38,769 ) $11,365 ($1,968 ) ($29,372 ) Entergy Louisiana Amortization of prior service credit $— $3,674 $— $3,674 Amortization of net gain (loss) (1,397 ) 348 (3 ) (1,052 ) ($1,397 ) $4,022 ($3 ) $2,622 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($198 ) $11,189 ($141 ) $10,850 Amortization of net loss (43,914 ) (3,865 ) (1,981 ) (49,760 ) Settlement loss — — (2,022 ) (2,022 ) ($44,112 ) $7,324 ($4,144 ) ($40,932 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of net loss (1,734 ) (775 ) (4 ) (2,513 ) ($1,734 ) $3,093 ($4 ) $1,355 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019. As of June 30, 2019 , Entergy had contributed $65.5 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 June 2019 $9,338 $10,093 $2,671 $674 $739 $2,944 Remaining estimated pension contributions to be made in 2019 $17,774 $16,358 $5,030 $1,126 $906 $5,341
System Energy [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,606 $38,752 Interest cost on projected benefit obligation 73,912 66,854 Expected return on assets (103,859 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 58,420 68,526 Settlement charges 162 — Net pension costs $62,241 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $67,213 $77,504 Interest cost on projected benefit obligation 147,853 133,708 Expected return on assets (207,743 ) (221,070 ) Amortization of prior service cost — 198 Amortization of net loss 116,838 137,052 Settlement charges 1,299 — Net pension costs $125,460 $127,392 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second 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 $5,261 $7,284 $1,629 $569 $1,350 $1,550 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,874 3,612 3,363 Expected return on assets (20,176 ) (22,652 ) (5,968 ) (2,697 ) (5,862 ) (4,677 ) Amortization of net loss 11,841 11,643 3,105 1,530 2,334 2,850 Net pension cost $11,101 $12,157 $2,834 $1,276 $1,434 $3,086 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 six months ended June 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 $10,522 $14,568 $3,258 $1,138 $2,700 $3,100 Interest cost on projected benefit obligation 28,350 31,764 8,136 3,748 7,224 6,727 Expected return on assets (40,352 ) (45,304 ) (11,936 ) (5,393 ) (11,724 ) (9,354 ) Amortization of net loss 23,682 23,286 6,209 3,059 4,668 5,700 Net pension cost $22,202 $24,314 $5,667 $2,552 $2,868 $6,173 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $12,378 $16,892 $3,644 $1,346 $3,178 $3,552 Interest cost on projected benefit obligation 26,008 29,880 7,538 3,626 6,696 6,454 Expected return on assets (43,702 ) (49,618 ) (13,004 ) (5,986 ) (13,046 ) (9,982 ) Amortization of net loss 26,824 28,900 7,220 3,908 5,252 7,430 Net pension cost $21,508 $26,054 $5,398 $2,894 $2,080 $7,454 Non-Qualified Net Pension Cost Entergy recognized $7.6 million and $6.6 million in pension cost for its non-qualified pension plans in the second quarters of 2019 and 2018 , respectively. Reflected in the pension cost for non-qualified pension plans in the second quarters of 2019 and 2018 were settlement charges of $3.7 million and $2.4 million , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $11.6 million and $15.5 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the six months ended June 30, 2019 and 2018 were settlement charges of $3.7 million and $6.8 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 second quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $71 $41 $113 $6 $122 2018 $122 $46 $77 $21 $270 Reflected in Entergy Mississippi’s non-qualified pension costs in the second quarter of 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 in the second quarter of 2018 were settlement charges of $10 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs in the second quarter of 2018 were settlement charges of $139 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 six months ended June 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $144 $84 $188 $11 $246 2018 $254 $96 $157 $42 $407 Reflected in Entergy Mississippi’s non-qualified pension costs for the six months ended June 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 six months ended June 30, 2018 were settlement charges of $22 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the six months ended June 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 Entergy’s other postretirement benefit cost, including amounts capitalized, for the second 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, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $9,350 $13,564 Interest cost on accumulated postretirement benefit obligation (APBO) 23,950 25,362 Expected return on assets (19,124 ) (20,746 ) Amortization of prior service credit (17,688 ) (18,502 ) Amortization of net loss 716 6,864 Net other postretirement benefit cost (income) ($2,796 ) $6,542 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for second 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, including amounts capitalized, for their employees for the six months ended June 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 $1,182 $2,320 $524 $184 $472 $486 Interest cost on APBO 3,614 5,332 1,340 790 1,708 952 Expected return on assets (7,982 ) — (2,398 ) (2,474 ) (4,552 ) (1,394 ) Amortization of prior service credit (2,476 ) (3,674 ) (878 ) (342 ) (1,122 ) (726 ) Amortization of net (gain) loss 288 (348 ) 362 116 242 178 Net other postretirement benefit cost (income) ($5,374 ) $3,630 ($1,050 ) ($1,726 ) ($3,252 ) ($504 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,586 $3,112 $642 $258 $660 $612 Interest cost on APBO 3,994 5,578 1,366 834 1,878 1,000 Expected return on assets (8,684 ) — (2,606 ) (2,626 ) (4,892 ) (1,566 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of net loss 578 776 754 68 412 466 Net other postretirement benefit cost (income) ($5,082 ) $5,598 ($756 ) ($1,838 ) ($3,100 ) ($244 ) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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) (18,736 ) 308 (552 ) (18,980 ) Settlement loss (162 ) — (756 ) (918 ) ($18,898 ) $5,683 ($1,358 ) ($14,573 ) 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 ) $5,594 ($71 ) $5,424 Amortization of net loss (21,957 ) (1,933 ) (918 ) (24,808 ) Settlement loss — — (406 ) (406 ) ($22,056 ) $3,661 ($1,395 ) ($19,790 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (387 ) (2 ) (1,256 ) ($867 ) $1,547 ($2 ) $678 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,750 ($98 ) $10,652 Amortization of net gain (loss) (37,470 ) 615 (1,114 ) (37,969 ) Settlement loss (1,299 ) — (756 ) (2,055 ) ($38,769 ) $11,365 ($1,968 ) ($29,372 ) Entergy Louisiana Amortization of prior service credit $— $3,674 $— $3,674 Amortization of net gain (loss) (1,397 ) 348 (3 ) (1,052 ) ($1,397 ) $4,022 ($3 ) $2,622 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($198 ) $11,189 ($141 ) $10,850 Amortization of net loss (43,914 ) (3,865 ) (1,981 ) (49,760 ) Settlement loss — — (2,022 ) (2,022 ) ($44,112 ) $7,324 ($4,144 ) ($40,932 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of net loss (1,734 ) (775 ) (4 ) (2,513 ) ($1,734 ) $3,093 ($4 ) $1,355 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019. As of June 30, 2019 , Entergy had contributed $65.5 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 June 2019 $9,338 $10,093 $2,671 $674 $739 $2,944 Remaining estimated pension contributions to be made in 2019 $17,774 $16,358 $5,030 $1,126 $906 $5,341

Business Segment Information

Business Segment Information	6 Months Ended
	Jun. 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 June 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 second quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,376,437 $289,783 $2 ($13 ) $2,666,209 Income taxes $21,150 ($9,290 ) ($10,402 ) $— $1,458 Consolidated net income (loss) $334,752 ($25,382 ) ($36,939 ) ($31,898 ) $240,533 2018 Operating revenues $2,360,208 $308,602 $— ($40 ) $2,668,770 Income taxes ($240,324 ) ($30,144 ) ($10,128 ) $— ($280,596 ) Consolidated net income (loss) $378,394 ($56,337 ) ($41,299 ) ($31,898 ) $248,860 Entergy’s segment financial information for the six months ended June 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $4,552,419 $723,394 $2 ($23) $5,275,792 Income taxes $9,586 $56,618 ($21,975) $— $44,229 Consolidated net income (loss) $568,900 $71,697 ($77,620) ($63,797) $499,180 Total assets as of June 30, 2019 $47,297,832 $5,211,771 $493,962 ($2,437,820) $50,565,745 2018 Operating revenues $4,665,197 $727,526 $— ($73) $5,392,650 Income taxes ($188,100) ($31,222) ($17,611) $— ($236,933) Consolidated net income (loss) $596,333 ($74,116) ($73,361) ($63,797) $385,059 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 second 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 April 1, $213 $14 $227 $109 $14 $123 Restructuring costs accrued 22 — 22 34 — 34 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $16 million in the second quarter 2019 and $69 million in the second quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 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 56 — 56 60 — 60 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $90 million in the six months ended June 30, 2019 and $142 million in the six months ended June 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 $120 million in 2019, of which $56 million has been incurred as of June 30, 2019, and a total of approximately $120 million from 2020 through mid-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 June 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 second quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,376,437 $289,783 $2 ($13 ) $2,666,209 Income taxes $21,150 ($9,290 ) ($10,402 ) $— $1,458 Consolidated net income (loss) $334,752 ($25,382 ) ($36,939 ) ($31,898 ) $240,533 2018 Operating revenues $2,360,208 $308,602 $— ($40 ) $2,668,770 Income taxes ($240,324 ) ($30,144 ) ($10,128 ) $— ($280,596 ) Consolidated net income (loss) $378,394 ($56,337 ) ($41,299 ) ($31,898 ) $248,860 Entergy’s segment financial information for the six months ended June 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $4,552,419 $723,394 $2 ($23) $5,275,792 Income taxes $9,586 $56,618 ($21,975) $— $44,229 Consolidated net income (loss) $568,900 $71,697 ($77,620) ($63,797) $499,180 Total assets as of June 30, 2019 $47,297,832 $5,211,771 $493,962 ($2,437,820) $50,565,745 2018 Operating revenues $4,665,197 $727,526 $— ($73) $5,392,650 Income taxes ($188,100) ($31,222) ($17,611) $— ($236,933) Consolidated net income (loss) $596,333 ($74,116) ($73,361) ($63,797) $385,059 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 second 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 April 1, $213 $14 $227 $109 $14 $123 Restructuring costs accrued 22 — 22 34 — 34 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $16 million in the second quarter 2019 and $69 million in the second quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 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 56 — 56 60 — 60 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $90 million in the six months ended June 30, 2019 and $142 million in the six months ended June 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 $120 million in 2019, of which $56 million has been incurred as of June 30, 2019, and a total of approximately $120 million from 2020 through mid-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 June 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 second quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,376,437 $289,783 $2 ($13 ) $2,666,209 Income taxes $21,150 ($9,290 ) ($10,402 ) $— $1,458 Consolidated net income (loss) $334,752 ($25,382 ) ($36,939 ) ($31,898 ) $240,533 2018 Operating revenues $2,360,208 $308,602 $— ($40 ) $2,668,770 Income taxes ($240,324 ) ($30,144 ) ($10,128 ) $— ($280,596 ) Consolidated net income (loss) $378,394 ($56,337 ) ($41,299 ) ($31,898 ) $248,860 Entergy’s segment financial information for the six months ended June 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $4,552,419 $723,394 $2 ($23) $5,275,792 Income taxes $9,586 $56,618 ($21,975) $— $44,229 Consolidated net income (loss) $568,900 $71,697 ($77,620) ($63,797) $499,180 Total assets as of June 30, 2019 $47,297,832 $5,211,771 $493,962 ($2,437,820) $50,565,745 2018 Operating revenues $4,665,197 $727,526 $— ($73) $5,392,650 Income taxes ($188,100) ($31,222) ($17,611) $— ($236,933) Consolidated net income (loss) $596,333 ($74,116) ($73,361) ($63,797) $385,059 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 second 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 April 1, $213 $14 $227 $109 $14 $123 Restructuring costs accrued 22 — 22 34 — 34 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $16 million in the second quarter 2019 and $69 million in the second quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 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 56 — 56 60 — 60 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $90 million in the six months ended June 30, 2019 and $142 million in the six months ended June 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 $120 million in 2019, of which $56 million has been incurred as of June 30, 2019, and a total of approximately $120 million from 2020 through mid-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 June 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 second quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,376,437 $289,783 $2 ($13 ) $2,666,209 Income taxes $21,150 ($9,290 ) ($10,402 ) $— $1,458 Consolidated net income (loss) $334,752 ($25,382 ) ($36,939 ) ($31,898 ) $240,533 2018 Operating revenues $2,360,208 $308,602 $— ($40 ) $2,668,770 Income taxes ($240,324 ) ($30,144 ) ($10,128 ) $— ($280,596 ) Consolidated net income (loss) $378,394 ($56,337 ) ($41,299 ) ($31,898 ) $248,860 Entergy’s segment financial information for the six months ended June 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $4,552,419 $723,394 $2 ($23) $5,275,792 Income taxes $9,586 $56,618 ($21,975) $— $44,229 Consolidated net income (loss) $568,900 $71,697 ($77,620) ($63,797) $499,180 Total assets as of June 30, 2019 $47,297,832 $5,211,771 $493,962 ($2,437,820) $50,565,745 2018 Operating revenues $4,665,197 $727,526 $— ($73) $5,392,650 Income taxes ($188,100) ($31,222) ($17,611) $— ($236,933) Consolidated net income (loss) $596,333 ($74,116) ($73,361) ($63,797) $385,059 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 second 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 April 1, $213 $14 $227 $109 $14 $123 Restructuring costs accrued 22 — 22 34 — 34 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $16 million in the second quarter 2019 and $69 million in the second quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 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 56 — 56 60 — 60 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $90 million in the six months ended June 30, 2019 and $142 million in the six months ended June 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 $120 million in 2019, of which $56 million has been incurred as of June 30, 2019, and a total of approximately $120 million from 2020 through mid-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 June 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 second quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,376,437 $289,783 $2 ($13 ) $2,666,209 Income taxes $21,150 ($9,290 ) ($10,402 ) $— $1,458 Consolidated net income (loss) $334,752 ($25,382 ) ($36,939 ) ($31,898 ) $240,533 2018 Operating revenues $2,360,208 $308,602 $— ($40 ) $2,668,770 Income taxes ($240,324 ) ($30,144 ) ($10,128 ) $— ($280,596 ) Consolidated net income (loss) $378,394 ($56,337 ) ($41,299 ) ($31,898 ) $248,860 Entergy’s segment financial information for the six months ended June 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $4,552,419 $723,394 $2 ($23) $5,275,792 Income taxes $9,586 $56,618 ($21,975) $— $44,229 Consolidated net income (loss) $568,900 $71,697 ($77,620) ($63,797) $499,180 Total assets as of June 30, 2019 $47,297,832 $5,211,771 $493,962 ($2,437,820) $50,565,745 2018 Operating revenues $4,665,197 $727,526 $— ($73) $5,392,650 Income taxes ($188,100) ($31,222) ($17,611) $— ($236,933) Consolidated net income (loss) $596,333 ($74,116) ($73,361) ($63,797) $385,059 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 second 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 April 1, $213 $14 $227 $109 $14 $123 Restructuring costs accrued 22 — 22 34 — 34 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $16 million in the second quarter 2019 and $69 million in the second quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 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 56 — 56 60 — 60 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $90 million in the six months ended June 30, 2019 and $142 million in the six months ended June 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 $120 million in 2019, of which $56 million has been incurred as of June 30, 2019, and a total of approximately $120 million from 2020 through mid-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 June 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 second quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,376,437 $289,783 $2 ($13 ) $2,666,209 Income taxes $21,150 ($9,290 ) ($10,402 ) $— $1,458 Consolidated net income (loss) $334,752 ($25,382 ) ($36,939 ) ($31,898 ) $240,533 2018 Operating revenues $2,360,208 $308,602 $— ($40 ) $2,668,770 Income taxes ($240,324 ) ($30,144 ) ($10,128 ) $— ($280,596 ) Consolidated net income (loss) $378,394 ($56,337 ) ($41,299 ) ($31,898 ) $248,860 Entergy’s segment financial information for the six months ended June 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $4,552,419 $723,394 $2 ($23) $5,275,792 Income taxes $9,586 $56,618 ($21,975) $— $44,229 Consolidated net income (loss) $568,900 $71,697 ($77,620) ($63,797) $499,180 Total assets as of June 30, 2019 $47,297,832 $5,211,771 $493,962 ($2,437,820) $50,565,745 2018 Operating revenues $4,665,197 $727,526 $— ($73) $5,392,650 Income taxes ($188,100) ($31,222) ($17,611) $— ($236,933) Consolidated net income (loss) $596,333 ($74,116) ($73,361) ($63,797) $385,059 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 second 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 April 1, $213 $14 $227 $109 $14 $123 Restructuring costs accrued 22 — 22 34 — 34 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $16 million in the second quarter 2019 and $69 million in the second quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 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 56 — 56 60 — 60 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $90 million in the six months ended June 30, 2019 and $142 million in the six months ended June 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 $120 million in 2019, of which $56 million has been incurred as of June 30, 2019, and a total of approximately $120 million from 2020 through mid-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 June 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 second quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,376,437 $289,783 $2 ($13 ) $2,666,209 Income taxes $21,150 ($9,290 ) ($10,402 ) $— $1,458 Consolidated net income (loss) $334,752 ($25,382 ) ($36,939 ) ($31,898 ) $240,533 2018 Operating revenues $2,360,208 $308,602 $— ($40 ) $2,668,770 Income taxes ($240,324 ) ($30,144 ) ($10,128 ) $— ($280,596 ) Consolidated net income (loss) $378,394 ($56,337 ) ($41,299 ) ($31,898 ) $248,860 Entergy’s segment financial information for the six months ended June 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $4,552,419 $723,394 $2 ($23) $5,275,792 Income taxes $9,586 $56,618 ($21,975) $— $44,229 Consolidated net income (loss) $568,900 $71,697 ($77,620) ($63,797) $499,180 Total assets as of June 30, 2019 $47,297,832 $5,211,771 $493,962 ($2,437,820) $50,565,745 2018 Operating revenues $4,665,197 $727,526 $— ($73) $5,392,650 Income taxes ($188,100) ($31,222) ($17,611) $— ($236,933) Consolidated net income (loss) $596,333 ($74,116) ($73,361) ($63,797) $385,059 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 second 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 April 1, $213 $14 $227 $109 $14 $123 Restructuring costs accrued 22 — 22 34 — 34 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $16 million in the second quarter 2019 and $69 million in the second quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 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 56 — 56 60 — 60 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $90 million in the six months ended June 30, 2019 and $142 million in the six months ended June 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 $120 million in 2019, of which $56 million has been incurred as of June 30, 2019, and a total of approximately $120 million from 2020 through mid-2022. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

Risk Management And Fair Values

Risk Management And Fair Values	6 Months Ended
	Jun. 30, 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 June 30, 2019 is approximately 1.75 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% 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 12.1 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 June 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 $51 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 June 30, 2019 is 4.75 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of June 30, 2019 is 9 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of June 30, 2019 is 41,300,000 MMBtu for Entergy, including 34,720,000 MMBtu for Entergy Louisiana and 6,580,000 MMBtu for Entergy Mississippi. 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 June 30, 2019 is 110,968 GWh for Entergy, including 25,480 GWh for Entergy Arkansas, 50,209 GWh for Entergy Louisiana, 14,072 GWh for Entergy Mississippi, 5,160 GWh for Entergy New Orleans, and 15,608 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 June 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of June 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 June 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) $51 ($2) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $21 ($2) $19 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $3 ($3) $— 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) $8 ($3) $5 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) $1 $— $1 Utility Financial transmission rights Prepayments and other $31 ($2) $29 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $3 ($3) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($1) $1 Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $5 $— $5 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 June 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $51 million held and $2 million posted as of June 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 June 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 $126 Competitive businesses operating revenues $6 2018 Electricity swaps and options ($80) Competitive businesses operating revenues $3 (a) Before taxes of $1 million and $1 million for the three months ended June 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 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 $152 Competitive businesses operating revenues $57 2018 Electricity swaps and options $11 Competitive businesses operating revenues ($27) (a) Before taxes of $12 million and ($6) million for the six months ended June 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 June 30, 2018 was ($15) million . The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2018 was ($2) million . Based on market prices as of June 30, 2019 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $67 million of net unrealized losses. Approximately $48 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 June 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) ($6) Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $41 Electricity swaps and options $— (c) Competitive business operating revenues $1 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 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) ($7) Financial transmission rights $— Purchased power expense (b) $53 Electricity swaps and options $— (c) Competitive business operating revenues $3 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $73 Electricity swaps and options $— (c) Competitive business operating revenues $1 (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 June 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) $1.4 $— $1.4 Entergy Louisiana Financial transmission rights Prepayments and other $8.3 ($0.1) $8.2 Entergy Arkansas Financial transmission rights Prepayments and other $15.9 ($0.3) $15.6 Entergy Louisiana Financial transmission rights Prepayments and other $2.8 $— $2.8 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 ($0.1) $2.0 Entergy New Orleans Financial transmission rights Prepayments and other $2.1 ($1.5) $0.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $1.9 $— $1.9 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $0.7 $— $0.7 Entergy Louisiana Natural gas swaps Other current liabilities $3.1 $— $3.1 Entergy Mississippi 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 June 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 ($2.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $3.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense $2.2 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.8 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $2.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $25.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $9.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($1.8) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($1.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.2) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.2 (a) Entergy New Orleans Financial transmission rights Purchased power expense $12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $26.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $8.1 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.7 (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 $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $43.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $17.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $8.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.3) (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 C
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 June 30, 2019 is approximately 1.75 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% 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 12.1 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 June 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 $51 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 June 30, 2019 is 4.75 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of June 30, 2019 is 9 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of June 30, 2019 is 41,300,000 MMBtu for Entergy, including 34,720,000 MMBtu for Entergy Louisiana and 6,580,000 MMBtu for Entergy Mississippi. 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 June 30, 2019 is 110,968 GWh for Entergy, including 25,480 GWh for Entergy Arkansas, 50,209 GWh for Entergy Louisiana, 14,072 GWh for Entergy Mississippi, 5,160 GWh for Entergy New Orleans, and 15,608 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 June 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of June 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 June 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) $51 ($2) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $21 ($2) $19 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $3 ($3) $— 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) $8 ($3) $5 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) $1 $— $1 Utility Financial transmission rights Prepayments and other $31 ($2) $29 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $3 ($3) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($1) $1 Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $5 $— $5 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 June 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $51 million held and $2 million posted as of June 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 June 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 $126 Competitive businesses operating revenues $6 2018 Electricity swaps and options ($80) Competitive businesses operating revenues $3 (a) Before taxes of $1 million and $1 million for the three months ended June 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 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 $152 Competitive businesses operating revenues $57 2018 Electricity swaps and options $11 Competitive businesses operating revenues ($27) (a) Before taxes of $12 million and ($6) million for the six months ended June 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 June 30, 2018 was ($15) million . The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2018 was ($2) million . Based on market prices as of June 30, 2019 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $67 million of net unrealized losses. Approximately $48 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 June 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) ($6) Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $41 Electricity swaps and options $— (c) Competitive business operating revenues $1 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 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) ($7) Financial transmission rights $— Purchased power expense (b) $53 Electricity swaps and options $— (c) Competitive business operating revenues $3 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $73 Electricity swaps and options $— (c) Competitive business operating revenues $1 (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 June 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) $1.4 $— $1.4 Entergy Louisiana Financial transmission rights Prepayments and other $8.3 ($0.1) $8.2 Entergy Arkansas Financial transmission rights Prepayments and other $15.9 ($0.3) $15.6 Entergy Louisiana Financial transmission rights Prepayments and other $2.8 $— $2.8 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 ($0.1) $2.0 Entergy New Orleans Financial transmission rights Prepayments and other $2.1 ($1.5) $0.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $1.9 $— $1.9 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $0.7 $— $0.7 Entergy Louisiana Natural gas swaps Other current liabilities $3.1 $— $3.1 Entergy Mississippi 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 June 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 ($2.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $3.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense $2.2 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.8 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $2.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $25.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $9.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($1.8) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($1.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.2) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.2 (a) Entergy New Orleans Financial transmission rights Purchased power expense $12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $26.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $8.1 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.7 (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 $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $43.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $17.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $8.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.3) (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 C
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 June 30, 2019 is approximately 1.75 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% 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 12.1 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 June 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 $51 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 June 30, 2019 is 4.75 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of June 30, 2019 is 9 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of June 30, 2019 is 41,300,000 MMBtu for Entergy, including 34,720,000 MMBtu for Entergy Louisiana and 6,580,000 MMBtu for Entergy Mississippi. 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 June 30, 2019 is 110,968 GWh for Entergy, including 25,480 GWh for Entergy Arkansas, 50,209 GWh for Entergy Louisiana, 14,072 GWh for Entergy Mississippi, 5,160 GWh for Entergy New Orleans, and 15,608 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 June 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of June 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 June 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) $51 ($2) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $21 ($2) $19 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $3 ($3) $— 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) $8 ($3) $5 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) $1 $— $1 Utility Financial transmission rights Prepayments and other $31 ($2) $29 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $3 ($3) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($1) $1 Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $5 $— $5 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 June 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $51 million held and $2 million posted as of June 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 June 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 $126 Competitive businesses operating revenues $6 2018 Electricity swaps and options ($80) Competitive businesses operating revenues $3 (a) Before taxes of $1 million and $1 million for the three months ended June 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 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 $152 Competitive businesses operating revenues $57 2018 Electricity swaps and options $11 Competitive businesses operating revenues ($27) (a) Before taxes of $12 million and ($6) million for the six months ended June 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 June 30, 2018 was ($15) million . The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2018 was ($2) million . Based on market prices as of June 30, 2019 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $67 million of net unrealized losses. Approximately $48 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 June 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) ($6) Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $41 Electricity swaps and options $— (c) Competitive business operating revenues $1 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 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) ($7) Financial transmission rights $— Purchased power expense (b) $53 Electricity swaps and options $— (c) Competitive business operating revenues $3 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $73 Electricity swaps and options $— (c) Competitive business operating revenues $1 (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 June 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) $1.4 $— $1.4 Entergy Louisiana Financial transmission rights Prepayments and other $8.3 ($0.1) $8.2 Entergy Arkansas Financial transmission rights Prepayments and other $15.9 ($0.3) $15.6 Entergy Louisiana Financial transmission rights Prepayments and other $2.8 $— $2.8 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 ($0.1) $2.0 Entergy New Orleans Financial transmission rights Prepayments and other $2.1 ($1.5) $0.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $1.9 $— $1.9 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $0.7 $— $0.7 Entergy Louisiana Natural gas swaps Other current liabilities $3.1 $— $3.1 Entergy Mississippi 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 June 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 ($2.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $3.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense $2.2 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.8 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $2.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $25.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $9.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($1.8) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($1.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.2) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.2 (a) Entergy New Orleans Financial transmission rights Purchased power expense $12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $26.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $8.1 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.7 (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 $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $43.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $17.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $8.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.3) (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 C
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 June 30, 2019 is approximately 1.75 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% 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 12.1 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 June 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 $51 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 June 30, 2019 is 4.75 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of June 30, 2019 is 9 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of June 30, 2019 is 41,300,000 MMBtu for Entergy, including 34,720,000 MMBtu for Entergy Louisiana and 6,580,000 MMBtu for Entergy Mississippi. 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 June 30, 2019 is 110,968 GWh for Entergy, including 25,480 GWh for Entergy Arkansas, 50,209 GWh for Entergy Louisiana, 14,072 GWh for Entergy Mississippi, 5,160 GWh for Entergy New Orleans, and 15,608 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 June 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of June 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 June 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) $51 ($2) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $21 ($2) $19 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $3 ($3) $— 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) $8 ($3) $5 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) $1 $— $1 Utility Financial transmission rights Prepayments and other $31 ($2) $29 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $3 ($3) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($1) $1 Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $5 $— $5 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 June 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $51 million held and $2 million posted as of June 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 June 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 $126 Competitive businesses operating revenues $6 2018 Electricity swaps and options ($80) Competitive businesses operating revenues $3 (a) Before taxes of $1 million and $1 million for the three months ended June 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 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 $152 Competitive businesses operating revenues $57 2018 Electricity swaps and options $11 Competitive businesses operating revenues ($27) (a) Before taxes of $12 million and ($6) million for the six months ended June 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 June 30, 2018 was ($15) million . The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2018 was ($2) million . Based on market prices as of June 30, 2019 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $67 million of net unrealized losses. Approximately $48 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 June 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) ($6) Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $41 Electricity swaps and options $— (c) Competitive business operating revenues $1 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 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) ($7) Financial transmission rights $— Purchased power expense (b) $53 Electricity swaps and options $— (c) Competitive business operating revenues $3 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $73 Electricity swaps and options $— (c) Competitive business operating revenues $1 (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 June 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) $1.4 $— $1.4 Entergy Louisiana Financial transmission rights Prepayments and other $8.3 ($0.1) $8.2 Entergy Arkansas Financial transmission rights Prepayments and other $15.9 ($0.3) $15.6 Entergy Louisiana Financial transmission rights Prepayments and other $2.8 $— $2.8 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 ($0.1) $2.0 Entergy New Orleans Financial transmission rights Prepayments and other $2.1 ($1.5) $0.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $1.9 $— $1.9 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $0.7 $— $0.7 Entergy Louisiana Natural gas swaps Other current liabilities $3.1 $— $3.1 Entergy Mississippi 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 June 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 ($2.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $3.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense $2.2 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.8 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $2.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $25.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $9.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($1.8) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($1.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.2) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.2 (a) Entergy New Orleans Financial transmission rights Purchased power expense $12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $26.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $8.1 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.7 (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 $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $43.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $17.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $8.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.3) (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 C
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 June 30, 2019 is approximately 1.75 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% 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 12.1 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 June 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 $51 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 June 30, 2019 is 4.75 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of June 30, 2019 is 9 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of June 30, 2019 is 41,300,000 MMBtu for Entergy, including 34,720,000 MMBtu for Entergy Louisiana and 6,580,000 MMBtu for Entergy Mississippi. 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 June 30, 2019 is 110,968 GWh for Entergy, including 25,480 GWh for Entergy Arkansas, 50,209 GWh for Entergy Louisiana, 14,072 GWh for Entergy Mississippi, 5,160 GWh for Entergy New Orleans, and 15,608 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 June 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of June 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 June 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) $51 ($2) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $21 ($2) $19 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $3 ($3) $— 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) $8 ($3) $5 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) $1 $— $1 Utility Financial transmission rights Prepayments and other $31 ($2) $29 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $3 ($3) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($1) $1 Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $5 $— $5 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 June 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $51 million held and $2 million posted as of June 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 June 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 $126 Competitive businesses operating revenues $6 2018 Electricity swaps and options ($80) Competitive businesses operating revenues $3 (a) Before taxes of $1 million and $1 million for the three months ended June 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 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 $152 Competitive businesses operating revenues $57 2018 Electricity swaps and options $11 Competitive businesses operating revenues ($27) (a) Before taxes of $12 million and ($6) million for the six months ended June 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 June 30, 2018 was ($15) million . The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2018 was ($2) million . Based on market prices as of June 30, 2019 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $67 million of net unrealized losses. Approximately $48 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 June 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) ($6) Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $41 Electricity swaps and options $— (c) Competitive business operating revenues $1 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 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) ($7) Financial transmission rights $— Purchased power expense (b) $53 Electricity swaps and options $— (c) Competitive business operating revenues $3 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $73 Electricity swaps and options $— (c) Competitive business operating revenues $1 (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 June 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) $1.4 $— $1.4 Entergy Louisiana Financial transmission rights Prepayments and other $8.3 ($0.1) $8.2 Entergy Arkansas Financial transmission rights Prepayments and other $15.9 ($0.3) $15.6 Entergy Louisiana Financial transmission rights Prepayments and other $2.8 $— $2.8 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 ($0.1) $2.0 Entergy New Orleans Financial transmission rights Prepayments and other $2.1 ($1.5) $0.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $1.9 $— $1.9 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $0.7 $— $0.7 Entergy Louisiana Natural gas swaps Other current liabilities $3.1 $— $3.1 Entergy Mississippi 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 June 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 ($2.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $3.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense $2.2 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.8 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $2.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $25.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $9.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($1.8) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($1.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.2) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.2 (a) Entergy New Orleans Financial transmission rights Purchased power expense $12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $26.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $8.1 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.7 (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 $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $43.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $17.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $8.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.3) (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 C
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 June 30, 2019 is approximately 1.75 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% 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 12.1 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 June 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 $51 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 June 30, 2019 is 4.75 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of June 30, 2019 is 9 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of June 30, 2019 is 41,300,000 MMBtu for Entergy, including 34,720,000 MMBtu for Entergy Louisiana and 6,580,000 MMBtu for Entergy Mississippi. 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 June 30, 2019 is 110,968 GWh for Entergy, including 25,480 GWh for Entergy Arkansas, 50,209 GWh for Entergy Louisiana, 14,072 GWh for Entergy Mississippi, 5,160 GWh for Entergy New Orleans, and 15,608 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 June 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of June 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 June 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) $51 ($2) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $21 ($2) $19 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $3 ($3) $— 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) $8 ($3) $5 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) $1 $— $1 Utility Financial transmission rights Prepayments and other $31 ($2) $29 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $3 ($3) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($1) $1 Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $5 $— $5 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 June 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $51 million held and $2 million posted as of June 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 June 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 $126 Competitive businesses operating revenues $6 2018 Electricity swaps and options ($80) Competitive businesses operating revenues $3 (a) Before taxes of $1 million and $1 million for the three months ended June 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 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 $152 Competitive businesses operating revenues $57 2018 Electricity swaps and options $11 Competitive businesses operating revenues ($27) (a) Before taxes of $12 million and ($6) million for the six months ended June 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 June 30, 2018 was ($15) million . The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2018 was ($2) million . Based on market prices as of June 30, 2019 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $67 million of net unrealized losses. Approximately $48 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 June 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) ($6) Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $41 Electricity swaps and options $— (c) Competitive business operating revenues $1 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 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) ($7) Financial transmission rights $— Purchased power expense (b) $53 Electricity swaps and options $— (c) Competitive business operating revenues $3 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $73 Electricity swaps and options $— (c) Competitive business operating revenues $1 (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 June 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) $1.4 $— $1.4 Entergy Louisiana Financial transmission rights Prepayments and other $8.3 ($0.1) $8.2 Entergy Arkansas Financial transmission rights Prepayments and other $15.9 ($0.3) $15.6 Entergy Louisiana Financial transmission rights Prepayments and other $2.8 $— $2.8 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 ($0.1) $2.0 Entergy New Orleans Financial transmission rights Prepayments and other $2.1 ($1.5) $0.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $1.9 $— $1.9 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $0.7 $— $0.7 Entergy Louisiana Natural gas swaps Other current liabilities $3.1 $— $3.1 Entergy Mississippi 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 June 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 ($2.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $3.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense $2.2 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.8 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $2.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $25.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $9.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($1.8) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($1.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.2) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.2 (a) Entergy New Orleans Financial transmission rights Purchased power expense $12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $26.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $8.1 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.7 (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 $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $43.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $17.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $8.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.3) (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 C
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 June 30, 2019 is approximately 1.75 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% 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 12.1 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 June 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 $51 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 June 30, 2019 is 4.75 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of June 30, 2019 is 9 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of June 30, 2019 is 41,300,000 MMBtu for Entergy, including 34,720,000 MMBtu for Entergy Louisiana and 6,580,000 MMBtu for Entergy Mississippi. 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 June 30, 2019 is 110,968 GWh for Entergy, including 25,480 GWh for Entergy Arkansas, 50,209 GWh for Entergy Louisiana, 14,072 GWh for Entergy Mississippi, 5,160 GWh for Entergy New Orleans, and 15,608 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 June 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of June 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 June 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) $51 ($2) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $21 ($2) $19 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $3 ($3) $— 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) $8 ($3) $5 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) $1 $— $1 Utility Financial transmission rights Prepayments and other $31 ($2) $29 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $3 ($3) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($1) $1 Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $5 $— $5 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 June 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $51 million held and $2 million posted as of June 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 June 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 $126 Competitive businesses operating revenues $6 2018 Electricity swaps and options ($80) Competitive businesses operating revenues $3 (a) Before taxes of $1 million and $1 million for the three months ended June 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 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 $152 Competitive businesses operating revenues $57 2018 Electricity swaps and options $11 Competitive businesses operating revenues ($27) (a) Before taxes of $12 million and ($6) million for the six months ended June 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 June 30, 2018 was ($15) million . The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2018 was ($2) million . Based on market prices as of June 30, 2019 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $67 million of net unrealized losses. Approximately $48 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 June 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) ($6) Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $41 Electricity swaps and options $— (c) Competitive business operating revenues $1 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 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) ($7) Financial transmission rights $— Purchased power expense (b) $53 Electricity swaps and options $— (c) Competitive business operating revenues $3 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $73 Electricity swaps and options $— (c) Competitive business operating revenues $1 (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 June 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) $1.4 $— $1.4 Entergy Louisiana Financial transmission rights Prepayments and other $8.3 ($0.1) $8.2 Entergy Arkansas Financial transmission rights Prepayments and other $15.9 ($0.3) $15.6 Entergy Louisiana Financial transmission rights Prepayments and other $2.8 $— $2.8 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 ($0.1) $2.0 Entergy New Orleans Financial transmission rights Prepayments and other $2.1 ($1.5) $0.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $1.9 $— $1.9 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $0.7 $— $0.7 Entergy Louisiana Natural gas swaps Other current liabilities $3.1 $— $3.1 Entergy Mississippi 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 June 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 ($2.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $3.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense $2.2 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.8 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $2.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $25.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $9.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($1.8) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($1.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.2) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.2 (a) Entergy New Orleans Financial transmission rights Purchased power expense $12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $26.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $8.1 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.7 (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 $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $43.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $17.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $8.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.3) (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 C

Decommissioning Trust Funds

Decommissioning Trust Funds	6 Months Ended
	Jun. 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, Pilgrim, 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 . 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 Pilgrim, 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 six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $7 million and $278 million , respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities (a) $2,914 $92 $2 2018 Debt Securities (a) $2,495 $19 $35 (a) Debt securities presented herein do not include the $499 million and $389 million of debt securities held in the wholly-owned registered investment company as of June 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 $15 million as of June 30, 2019 and ($1) million as of December 31, 2018 for debt securities. The amortized cost of available-for-sale debt securities was $2,849 million as of June 30, 2019 and $2,511 million as of December 31, 2018 . As of June 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 3.15% , an average duration of approximately 5.33 years, and an average maturity of approximately 8.51 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $163 $— More than 12 months 180 2 Total $343 $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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $226 $199 1 year - 5 years 1,342 1,066 5 years - 10 years 654 544 10 years - 15 years 64 77 15 years - 20 years 91 78 20 years+ 537 531 Total $2,914 $2,495 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $361 million and $710 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $6 million and $1 million , respectively, and gross losses of $1 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 six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $726 million and $1,801 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $8 million and $2 million , respectively, and gross losses of $3 million and $22 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 June 30, 2019 are $525 million for Indian Point 1, $664 million for Indian Point 2, $876 million for Indian Point 3, $489 million for Palisades, and $1,035 million for Pilgrim. 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 June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $401.6 $8.8 $0.5 2018 Debt Securities $381.3 $0.6 $8.2 The amortized cost of available-for-sale debt securities was $393.2 million as of June 30, 2019 and $389 million as of December 31, 2018 . As of June 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 2.75% , an average duration of approximately 4.76 years, and an average maturity of approximately 7.22 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $23 million and $93.8 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $0.5 $— More than 12 months 52.7 0.5 Total $53.2 $0.5 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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $59.5 $32.5 1 year - 5 years 143.2 170.3 5 years - 10 years 129.0 114.0 10 years - 15 years 11.1 10.3 15 years - 20 years 9.7 8.1 20 years+ 49.1 46.1 Total $401.6 $381.3 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $22.3 million and $86.5 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $0.1 million and $0.01 million , respectively, and gross losses of $18 thousand and $2.3 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $33.2 million and $121.4 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $0.1 million and $0.1 million , respectively, and gross losses of $0.1 million and $2.4 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $576.3 $26.6 $0.3 2018 Debt Securities $532.9 $4.1 $6.0 The amortized cost of available-for-sale debt securities was $550 million as of June 30, 2019 and $534.8 million as of December 31, 2018 . As of June 30, 2019 , the available-for-sale debt securities have an average coupon rate of approximately 3.87% , an average duration of approximately 6.46 years, and an average maturity of approximately 12.99 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $32.3 million and $131.1 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $5.0 $— More than 12 months 31.7 0.3 Total $36.7 $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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $52.5 $31.1 1 year - 5 years 128.7 130.5 5 years - 10 years 134.4 111.0 10 years - 15 years 27.6 29.0 15 years - 20 years 44.3 37.1 20 years+ 188.8 194.2 Total $576.3 $532.9 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $39.5 million and $43.9 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $1.4 million and $0.01 million , respectively, and gross losses of $0.05 million and $0.4 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $95.7 million and $169.4 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $1.7 million and $0.5 million , respectively, and gross losses of $0.2 million and $1.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $386.6 $14.1 $0.2 2018 Debt Securities $364.2 $2.9 $5.8 The amortized cost of available-for-sale debt securities was $372.7 million as of June 30, 2019 and $367.1 million as of December 31, 2018 . As of June 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 2.98% , an average duration of approximately 6.56 years, and an average maturity of approximately 9.13 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $21.8 million and $89.2 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $42.6 $0.1 More than 12 months 14.1 0.1 Total $56.7 $0.2 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 $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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $11.3 $22.8 1 year - 5 years 197.6 188.0 5 years - 10 years 90.5 73.4 10 years - 15 years 1.7 5.2 15 years - 20 years 3.2 10.2 20 years+ 82.3 64.6 Total $386.6 $364.2 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $87.7 million and $145.2 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $1.5 million and $0.2 million , respectively, and gross losses of $0.3 million and $3.9 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $129.8 million and $199.4 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $1.9 million and $0.3 million , respectively, and gross losses of $0.4 million and $4.5 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 six months ended June 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, Pilgrim, 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 . 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 Pilgrim, 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 six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $7 million and $278 million , respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities (a) $2,914 $92 $2 2018 Debt Securities (a) $2,495 $19 $35 (a) Debt securities presented herein do not include the $499 million and $389 million of debt securities held in the wholly-owned registered investment company as of June 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 $15 million as of June 30, 2019 and ($1) million as of December 31, 2018 for debt securities. The amortized cost of available-for-sale debt securities was $2,849 million as of June 30, 2019 and $2,511 million as of December 31, 2018 . As of June 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 3.15% , an average duration of approximately 5.33 years, and an average maturity of approximately 8.51 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $163 $— More than 12 months 180 2 Total $343 $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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $226 $199 1 year - 5 years 1,342 1,066 5 years - 10 years 654 544 10 years - 15 years 64 77 15 years - 20 years 91 78 20 years+ 537 531 Total $2,914 $2,495 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $361 million and $710 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $6 million and $1 million , respectively, and gross losses of $1 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 six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $726 million and $1,801 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $8 million and $2 million , respectively, and gross losses of $3 million and $22 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 June 30, 2019 are $525 million for Indian Point 1, $664 million for Indian Point 2, $876 million for Indian Point 3, $489 million for Palisades, and $1,035 million for Pilgrim. 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 June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $401.6 $8.8 $0.5 2018 Debt Securities $381.3 $0.6 $8.2 The amortized cost of available-for-sale debt securities was $393.2 million as of June 30, 2019 and $389 million as of December 31, 2018 . As of June 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 2.75% , an average duration of approximately 4.76 years, and an average maturity of approximately 7.22 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $23 million and $93.8 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $0.5 $— More than 12 months 52.7 0.5 Total $53.2 $0.5 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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $59.5 $32.5 1 year - 5 years 143.2 170.3 5 years - 10 years 129.0 114.0 10 years - 15 years 11.1 10.3 15 years - 20 years 9.7 8.1 20 years+ 49.1 46.1 Total $401.6 $381.3 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $22.3 million and $86.5 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $0.1 million and $0.01 million , respectively, and gross losses of $18 thousand and $2.3 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $33.2 million and $121.4 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $0.1 million and $0.1 million , respectively, and gross losses of $0.1 million and $2.4 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $576.3 $26.6 $0.3 2018 Debt Securities $532.9 $4.1 $6.0 The amortized cost of available-for-sale debt securities was $550 million as of June 30, 2019 and $534.8 million as of December 31, 2018 . As of June 30, 2019 , the available-for-sale debt securities have an average coupon rate of approximately 3.87% , an average duration of approximately 6.46 years, and an average maturity of approximately 12.99 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $32.3 million and $131.1 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $5.0 $— More than 12 months 31.7 0.3 Total $36.7 $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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $52.5 $31.1 1 year - 5 years 128.7 130.5 5 years - 10 years 134.4 111.0 10 years - 15 years 27.6 29.0 15 years - 20 years 44.3 37.1 20 years+ 188.8 194.2 Total $576.3 $532.9 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $39.5 million and $43.9 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $1.4 million and $0.01 million , respectively, and gross losses of $0.05 million and $0.4 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $95.7 million and $169.4 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $1.7 million and $0.5 million , respectively, and gross losses of $0.2 million and $1.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $386.6 $14.1 $0.2 2018 Debt Securities $364.2 $2.9 $5.8 The amortized cost of available-for-sale debt securities was $372.7 million as of June 30, 2019 and $367.1 million as of December 31, 2018 . As of June 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 2.98% , an average duration of approximately 6.56 years, and an average maturity of approximately 9.13 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $21.8 million and $89.2 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $42.6 $0.1 More than 12 months 14.1 0.1 Total $56.7 $0.2 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 $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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $11.3 $22.8 1 year - 5 years 197.6 188.0 5 years - 10 years 90.5 73.4 10 years - 15 years 1.7 5.2 15 years - 20 years 3.2 10.2 20 years+ 82.3 64.6 Total $386.6 $364.2 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $87.7 million and $145.2 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $1.5 million and $0.2 million , respectively, and gross losses of $0.3 million and $3.9 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $129.8 million and $199.4 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $1.9 million and $0.3 million , respectively, and gross losses of $0.4 million and $4.5 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 six months ended June 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, Pilgrim, 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 . 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 Pilgrim, 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 six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $7 million and $278 million , respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities (a) $2,914 $92 $2 2018 Debt Securities (a) $2,495 $19 $35 (a) Debt securities presented herein do not include the $499 million and $389 million of debt securities held in the wholly-owned registered investment company as of June 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 $15 million as of June 30, 2019 and ($1) million as of December 31, 2018 for debt securities. The amortized cost of available-for-sale debt securities was $2,849 million as of June 30, 2019 and $2,511 million as of December 31, 2018 . As of June 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 3.15% , an average duration of approximately 5.33 years, and an average maturity of approximately 8.51 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $163 $— More than 12 months 180 2 Total $343 $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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $226 $199 1 year - 5 years 1,342 1,066 5 years - 10 years 654 544 10 years - 15 years 64 77 15 years - 20 years 91 78 20 years+ 537 531 Total $2,914 $2,495 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $361 million and $710 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $6 million and $1 million , respectively, and gross losses of $1 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 six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $726 million and $1,801 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $8 million and $2 million , respectively, and gross losses of $3 million and $22 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 June 30, 2019 are $525 million for Indian Point 1, $664 million for Indian Point 2, $876 million for Indian Point 3, $489 million for Palisades, and $1,035 million for Pilgrim. 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 June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $401.6 $8.8 $0.5 2018 Debt Securities $381.3 $0.6 $8.2 The amortized cost of available-for-sale debt securities was $393.2 million as of June 30, 2019 and $389 million as of December 31, 2018 . As of June 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 2.75% , an average duration of approximately 4.76 years, and an average maturity of approximately 7.22 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $23 million and $93.8 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $0.5 $— More than 12 months 52.7 0.5 Total $53.2 $0.5 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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $59.5 $32.5 1 year - 5 years 143.2 170.3 5 years - 10 years 129.0 114.0 10 years - 15 years 11.1 10.3 15 years - 20 years 9.7 8.1 20 years+ 49.1 46.1 Total $401.6 $381.3 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $22.3 million and $86.5 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $0.1 million and $0.01 million , respectively, and gross losses of $18 thousand and $2.3 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $33.2 million and $121.4 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $0.1 million and $0.1 million , respectively, and gross losses of $0.1 million and $2.4 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $576.3 $26.6 $0.3 2018 Debt Securities $532.9 $4.1 $6.0 The amortized cost of available-for-sale debt securities was $550 million as of June 30, 2019 and $534.8 million as of December 31, 2018 . As of June 30, 2019 , the available-for-sale debt securities have an average coupon rate of approximately 3.87% , an average duration of approximately 6.46 years, and an average maturity of approximately 12.99 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $32.3 million and $131.1 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $5.0 $— More than 12 months 31.7 0.3 Total $36.7 $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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $52.5 $31.1 1 year - 5 years 128.7 130.5 5 years - 10 years 134.4 111.0 10 years - 15 years 27.6 29.0 15 years - 20 years 44.3 37.1 20 years+ 188.8 194.2 Total $576.3 $532.9 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $39.5 million and $43.9 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $1.4 million and $0.01 million , respectively, and gross losses of $0.05 million and $0.4 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $95.7 million and $169.4 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $1.7 million and $0.5 million , respectively, and gross losses of $0.2 million and $1.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $386.6 $14.1 $0.2 2018 Debt Securities $364.2 $2.9 $5.8 The amortized cost of available-for-sale debt securities was $372.7 million as of June 30, 2019 and $367.1 million as of December 31, 2018 . As of June 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 2.98% , an average duration of approximately 6.56 years, and an average maturity of approximately 9.13 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $21.8 million and $89.2 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $42.6 $0.1 More than 12 months 14.1 0.1 Total $56.7 $0.2 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 $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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $11.3 $22.8 1 year - 5 years 197.6 188.0 5 years - 10 years 90.5 73.4 10 years - 15 years 1.7 5.2 15 years - 20 years 3.2 10.2 20 years+ 82.3 64.6 Total $386.6 $364.2 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $87.7 million and $145.2 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $1.5 million and $0.2 million , respectively, and gross losses of $0.3 million and $3.9 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $129.8 million and $199.4 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $1.9 million and $0.3 million , respectively, and gross losses of $0.4 million and $4.5 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 six months ended June 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, Pilgrim, 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 . 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 Pilgrim, 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 six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $7 million and $278 million , respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities (a) $2,914 $92 $2 2018 Debt Securities (a) $2,495 $19 $35 (a) Debt securities presented herein do not include the $499 million and $389 million of debt securities held in the wholly-owned registered investment company as of June 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 $15 million as of June 30, 2019 and ($1) million as of December 31, 2018 for debt securities. The amortized cost of available-for-sale debt securities was $2,849 million as of June 30, 2019 and $2,511 million as of December 31, 2018 . As of June 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 3.15% , an average duration of approximately 5.33 years, and an average maturity of approximately 8.51 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $163 $— More than 12 months 180 2 Total $343 $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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $226 $199 1 year - 5 years 1,342 1,066 5 years - 10 years 654 544 10 years - 15 years 64 77 15 years - 20 years 91 78 20 years+ 537 531 Total $2,914 $2,495 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $361 million and $710 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $6 million and $1 million , respectively, and gross losses of $1 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 six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $726 million and $1,801 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $8 million and $2 million , respectively, and gross losses of $3 million and $22 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 June 30, 2019 are $525 million for Indian Point 1, $664 million for Indian Point 2, $876 million for Indian Point 3, $489 million for Palisades, and $1,035 million for Pilgrim. 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 June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $401.6 $8.8 $0.5 2018 Debt Securities $381.3 $0.6 $8.2 The amortized cost of available-for-sale debt securities was $393.2 million as of June 30, 2019 and $389 million as of December 31, 2018 . As of June 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 2.75% , an average duration of approximately 4.76 years, and an average maturity of approximately 7.22 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $23 million and $93.8 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $0.5 $— More than 12 months 52.7 0.5 Total $53.2 $0.5 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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $59.5 $32.5 1 year - 5 years 143.2 170.3 5 years - 10 years 129.0 114.0 10 years - 15 years 11.1 10.3 15 years - 20 years 9.7 8.1 20 years+ 49.1 46.1 Total $401.6 $381.3 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $22.3 million and $86.5 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $0.1 million and $0.01 million , respectively, and gross losses of $18 thousand and $2.3 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $33.2 million and $121.4 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $0.1 million and $0.1 million , respectively, and gross losses of $0.1 million and $2.4 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $576.3 $26.6 $0.3 2018 Debt Securities $532.9 $4.1 $6.0 The amortized cost of available-for-sale debt securities was $550 million as of June 30, 2019 and $534.8 million as of December 31, 2018 . As of June 30, 2019 , the available-for-sale debt securities have an average coupon rate of approximately 3.87% , an average duration of approximately 6.46 years, and an average maturity of approximately 12.99 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $32.3 million and $131.1 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $5.0 $— More than 12 months 31.7 0.3 Total $36.7 $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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $52.5 $31.1 1 year - 5 years 128.7 130.5 5 years - 10 years 134.4 111.0 10 years - 15 years 27.6 29.0 15 years - 20 years 44.3 37.1 20 years+ 188.8 194.2 Total $576.3 $532.9 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $39.5 million and $43.9 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $1.4 million and $0.01 million , respectively, and gross losses of $0.05 million and $0.4 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $95.7 million and $169.4 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $1.7 million and $0.5 million , respectively, and gross losses of $0.2 million and $1.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $386.6 $14.1 $0.2 2018 Debt Securities $364.2 $2.9 $5.8 The amortized cost of available-for-sale debt securities was $372.7 million as of June 30, 2019 and $367.1 million as of December 31, 2018 . As of June 30, 2019 , available-for-sale debt securities have an average coupon rate of approximately 2.98% , an average duration of approximately 6.56 years, and an average maturity of approximately 9.13 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2019 on equity securities still held as of June 30, 2019 were $21.8 million and $89.2 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $42.6 $0.1 More than 12 months 14.1 0.1 Total $56.7 $0.2 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 $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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $11.3 $22.8 1 year - 5 years 197.6 188.0 5 years - 10 years 90.5 73.4 10 years - 15 years 1.7 5.2 15 years - 20 years 3.2 10.2 20 years+ 82.3 64.6 Total $386.6 $364.2 During the three months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $87.7 million and $145.2 million , respectively. During the three months ended June 30, 2019 and 2018 , gross gains of $1.5 million and $0.2 million , respectively, and gross losses of $0.3 million and $3.9 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2019 and 2018 , proceeds from the dispositions of available-for-sale securities amounted to $129.8 million and $199.4 million , respectively. During the six months ended June 30, 2019 and 2018 , gross gains of $1.9 million and $0.3 million , respectively, and gross losses of $0.4 million and $4.5 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 six months ended June 30, 2019 and 2018

Income Taxes

Income Taxes	6 Months Ended
	Jun. 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 the Registrant Subsidiaries’ regulatory liability for income taxes for the three months ended June 30, 2019 and 2018 and the six months ended June 30, 2019 and 2018, as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In Millions) Entergy Arkansas $25 $108 $57 $108 Entergy Louisiana 7 31 14 31 Entergy Mississippi — 129 — 129 Entergy New Orleans 2 — 2 — Entergy Texas 20 — 42 — System Entergy 7 11 7 11 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. 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 the Registrant Subsidiaries’ regulatory liability for income taxes for the three months ended June 30, 2019 and 2018 and the six months ended June 30, 2019 and 2018, as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In Millions) Entergy Arkansas $25 $108 $57 $108 Entergy Louisiana 7 31 14 31 Entergy Mississippi — 129 — 129 Entergy New Orleans 2 — 2 — Entergy Texas 20 — 42 — System Entergy 7 11 7 11 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. 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 the Registrant Subsidiaries’ regulatory liability for income taxes for the three months ended June 30, 2019 and 2018 and the six months ended June 30, 2019 and 2018, as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In Millions) Entergy Arkansas $25 $108 $57 $108 Entergy Louisiana 7 31 14 31 Entergy Mississippi — 129 — 129 Entergy New Orleans 2 — 2 — Entergy Texas 20 — 42 — System Entergy 7 11 7 11 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. 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 the Registrant Subsidiaries’ regulatory liability for income taxes for the three months ended June 30, 2019 and 2018 and the six months ended June 30, 2019 and 2018, as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In Millions) Entergy Arkansas $25 $108 $57 $108 Entergy Louisiana 7 31 14 31 Entergy Mississippi — 129 — 129 Entergy New Orleans 2 — 2 — Entergy Texas 20 — 42 — System Entergy 7 11 7 11 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. 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 the Registrant Subsidiaries’ regulatory liability for income taxes for the three months ended June 30, 2019 and 2018 and the six months ended June 30, 2019 and 2018, as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In Millions) Entergy Arkansas $25 $108 $57 $108 Entergy Louisiana 7 31 14 31 Entergy Mississippi — 129 — 129 Entergy New Orleans 2 — 2 — Entergy Texas 20 — 42 — System Entergy 7 11 7 11 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. 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 the Registrant Subsidiaries’ regulatory liability for income taxes for the three months ended June 30, 2019 and 2018 and the six months ended June 30, 2019 and 2018, as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In Millions) Entergy Arkansas $25 $108 $57 $108 Entergy Louisiana 7 31 14 31 Entergy Mississippi — 129 — 129 Entergy New Orleans 2 — 2 — Entergy Texas 20 — 42 — System Entergy 7 11 7 11 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. 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 the Registrant Subsidiaries’ regulatory liability for income taxes for the three months ended June 30, 2019 and 2018 and the six months ended June 30, 2019 and 2018, as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In Millions) Entergy Arkansas $25 $108 $57 $108 Entergy Louisiana 7 31 14 31 Entergy Mississippi — 129 — 129 Entergy New Orleans 2 — 2 — Entergy Texas 20 — 42 — System Entergy 7 11 7 11 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. 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	6 Months Ended
	Jun. 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 June 30, 2019 are $292 million for Entergy, $37.9 million for Entergy Arkansas, $71.3 million for Entergy Louisiana, $10.8 million for Entergy Mississippi, $9.9 million for Entergy New Orleans, $52.4 million for Entergy Texas, and $19.7 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 June 30, 2019 are $292 million for Entergy, $37.9 million for Entergy Arkansas, $71.3 million for Entergy Louisiana, $10.8 million for Entergy Mississippi, $9.9 million for Entergy New Orleans, $52.4 million for Entergy Texas, and $19.7 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 June 30, 2019 are $292 million for Entergy, $37.9 million for Entergy Arkansas, $71.3 million for Entergy Louisiana, $10.8 million for Entergy Mississippi, $9.9 million for Entergy New Orleans, $52.4 million for Entergy Texas, and $19.7 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 June 30, 2019 are $292 million for Entergy, $37.9 million for Entergy Arkansas, $71.3 million for Entergy Louisiana, $10.8 million for Entergy Mississippi, $9.9 million for Entergy New Orleans, $52.4 million for Entergy Texas, and $19.7 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 June 30, 2019 are $292 million for Entergy, $37.9 million for Entergy Arkansas, $71.3 million for Entergy Louisiana, $10.8 million for Entergy Mississippi, $9.9 million for Entergy New Orleans, $52.4 million for Entergy Texas, and $19.7 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 June 30, 2019 are $292 million for Entergy, $37.9 million for Entergy Arkansas, $71.3 million for Entergy Louisiana, $10.8 million for Entergy Mississippi, $9.9 million for Entergy New Orleans, $52.4 million for Entergy Texas, and $19.7 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 June 30, 2019 are $292 million for Entergy, $37.9 million for Entergy Arkansas, $71.3 million for Entergy Louisiana, $10.8 million for Entergy Mississippi, $9.9 million for Entergy New Orleans, $52.4 million for Entergy Texas, and $19.7 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	6 Months Ended
	Jun. 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 six months ended June 30, 2019 and in the six months ended June 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 six months ended June 30, 2019 and in the six months ended June 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 six months ended June 30, 2019 and in the six months ended June 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 six months ended June 30, 2019 and in the six months ended June 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 six months ended June 30, 2019 and in the six months ended June 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 six months ended June 30, 2019 and in the six months ended June 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 six months ended June 30, 2019 and in the six months ended June 30, 2018

Revenue Recognition

Revenue Recognition	6 Months Ended
	Jun. 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 June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $770,373 $768,710 Commercial 595,025 581,899 Industrial 641,733 624,818 Governmental 57,623 56,823 Total billed retail 2,064,754 2,032,250 Sales for resale (a) 75,318 69,212 Other electric revenues (b) 195,952 219,391 Non-customer revenues (c) 9,703 9,372 Total electric revenues 2,345,727 2,330,225 Natural gas 30,699 29,943 Entergy Wholesale Commodities: Competitive businesses sales (a) 280,398 331,562 Non-customer revenues (c) 9,385 (22,960 ) Total competitive businesses 289,783 308,602 Total operating revenues $2,666,209 $2,668,770 Entergy’s total revenues for the six months ended June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,572,911 $1,660,795 Commercial 1,149,082 1,177,620 Industrial 1,242,734 1,222,004 Governmental 110,584 113,301 Total billed retail 4,075,311 4,173,720 Sales for resale (a) 159,753 138,738 Other electric revenues (b) 211,422 246,822 Non-customer revenues (c) 20,265 19,206 Total electric revenues 4,466,751 4,578,486 Natural gas 85,647 86,638 Entergy Wholesale Commodities: Competitive businesses sales (a) 640,869 740,697 Non-customer revenues (c) 82,525 (13,171 ) Total competitive businesses 723,394 727,526 Total operating revenues $5,275,792 $5,392,650 The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $157,714 $290,366 $116,801 $58,621 $146,871 Commercial 125,555 232,134 102,275 53,981 81,080 Industrial 118,913 384,919 38,739 8,490 90,672 Governmental 4,971 17,925 10,521 18,984 5,222 Total billed retail 407,153 925,344 268,336 140,076 323,845 Sales for resale (a) 74,501 83,208 4,994 8,579 14,772 Other electric revenues (b) 58,209 80,307 26,982 7,263 24,656 Non-customer revenues (c) 3,066 5,400 2,425 1,234 307 Total electric revenues 542,929 1,094,259 302,737 157,152 363,580 Natural gas — 12,058 — 18,641 — Total operating revenues $542,929 $1,106,317 $302,737 $175,793 $363,580 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $159,130 $267,915 $132,730 $58,232 $150,703 Commercial 93,741 221,740 117,351 54,524 94,544 Industrial 97,973 368,678 46,129 9,267 102,771 Governmental 3,766 16,705 11,452 18,448 6,452 Total billed retail 354,610 875,038 307,662 140,471 354,470 Sales for resale (a) 53,195 111,801 11,776 6,190 25,177 Other electric revenues (b) 84,102 70,027 31,696 11,623 23,468 Non-customer revenues (c) 2,698 4,823 2,555 1,318 371 Total electric revenues 494,605 1,061,689 353,689 159,602 403,486 Natural gas — 11,099 — 18,844 — Total operating revenues $494,605 $1,072,788 $353,689 $178,446 $403,486 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $367,581 $554,431 $245,610 $110,697 $294,592 Commercial 250,133 438,912 200,189 99,723 160,125 Industrial 240,491 731,598 76,436 15,740 178,470 Governmental 9,869 34,817 20,557 34,886 10,455 Total billed retail 868,074 1,759,758 542,792 261,046 643,642 Sales for resale (a) 154,085 167,164 9,808 18,803 31,548 Other electric revenues (b) 60,514 92,746 27,387 5,556 28,153 Non-customer revenues (c) 6,068 11,284 4,994 2,630 711 Total electric revenues 1,088,741 2,030,952 584,981 288,035 704,054 Natural gas — 34,695 — 50,952 — Total operating revenues $1,088,741 $2,065,647 $584,981 $338,987 $704,054 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $394,654 $563,433 $281,073 $122,807 $298,828 Commercial 214,375 446,667 227,811 108,796 179,971 Industrial 209,450 721,014 88,629 16,838 186,073 Governmental 8,414 34,015 22,300 36,139 12,433 Total billed retail 826,893 1,765,129 619,813 284,580 677,305 Sales for resale (a) 119,299 201,056 13,769 19,527 48,538 Other electric revenues (b) 94,125 90,529 30,977 8,511 25,733 Non-customer revenues (c) 5,312 10,081 4,873 2,802 850 Total electric revenues 1,045,629 2,066,795 669,432 315,420 752,426 Natural gas — 35,337 — 51,301 — Total operating revenues $1,045,629 $2,102,132 $669,432 $366,721 $752,426 (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 June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $770,373 $768,710 Commercial 595,025 581,899 Industrial 641,733 624,818 Governmental 57,623 56,823 Total billed retail 2,064,754 2,032,250 Sales for resale (a) 75,318 69,212 Other electric revenues (b) 195,952 219,391 Non-customer revenues (c) 9,703 9,372 Total electric revenues 2,345,727 2,330,225 Natural gas 30,699 29,943 Entergy Wholesale Commodities: Competitive businesses sales (a) 280,398 331,562 Non-customer revenues (c) 9,385 (22,960 ) Total competitive businesses 289,783 308,602 Total operating revenues $2,666,209 $2,668,770 Entergy’s total revenues for the six months ended June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,572,911 $1,660,795 Commercial 1,149,082 1,177,620 Industrial 1,242,734 1,222,004 Governmental 110,584 113,301 Total billed retail 4,075,311 4,173,720 Sales for resale (a) 159,753 138,738 Other electric revenues (b) 211,422 246,822 Non-customer revenues (c) 20,265 19,206 Total electric revenues 4,466,751 4,578,486 Natural gas 85,647 86,638 Entergy Wholesale Commodities: Competitive businesses sales (a) 640,869 740,697 Non-customer revenues (c) 82,525 (13,171 ) Total competitive businesses 723,394 727,526 Total operating revenues $5,275,792 $5,392,650 The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $157,714 $290,366 $116,801 $58,621 $146,871 Commercial 125,555 232,134 102,275 53,981 81,080 Industrial 118,913 384,919 38,739 8,490 90,672 Governmental 4,971 17,925 10,521 18,984 5,222 Total billed retail 407,153 925,344 268,336 140,076 323,845 Sales for resale (a) 74,501 83,208 4,994 8,579 14,772 Other electric revenues (b) 58,209 80,307 26,982 7,263 24,656 Non-customer revenues (c) 3,066 5,400 2,425 1,234 307 Total electric revenues 542,929 1,094,259 302,737 157,152 363,580 Natural gas — 12,058 — 18,641 — Total operating revenues $542,929 $1,106,317 $302,737 $175,793 $363,580 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $159,130 $267,915 $132,730 $58,232 $150,703 Commercial 93,741 221,740 117,351 54,524 94,544 Industrial 97,973 368,678 46,129 9,267 102,771 Governmental 3,766 16,705 11,452 18,448 6,452 Total billed retail 354,610 875,038 307,662 140,471 354,470 Sales for resale (a) 53,195 111,801 11,776 6,190 25,177 Other electric revenues (b) 84,102 70,027 31,696 11,623 23,468 Non-customer revenues (c) 2,698 4,823 2,555 1,318 371 Total electric revenues 494,605 1,061,689 353,689 159,602 403,486 Natural gas — 11,099 — 18,844 — Total operating revenues $494,605 $1,072,788 $353,689 $178,446 $403,486 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $367,581 $554,431 $245,610 $110,697 $294,592 Commercial 250,133 438,912 200,189 99,723 160,125 Industrial 240,491 731,598 76,436 15,740 178,470 Governmental 9,869 34,817 20,557 34,886 10,455 Total billed retail 868,074 1,759,758 542,792 261,046 643,642 Sales for resale (a) 154,085 167,164 9,808 18,803 31,548 Other electric revenues (b) 60,514 92,746 27,387 5,556 28,153 Non-customer revenues (c) 6,068 11,284 4,994 2,630 711 Total electric revenues 1,088,741 2,030,952 584,981 288,035 704,054 Natural gas — 34,695 — 50,952 — Total operating revenues $1,088,741 $2,065,647 $584,981 $338,987 $704,054 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $394,654 $563,433 $281,073 $122,807 $298,828 Commercial 214,375 446,667 227,811 108,796 179,971 Industrial 209,450 721,014 88,629 16,838 186,073 Governmental 8,414 34,015 22,300 36,139 12,433 Total billed retail 826,893 1,765,129 619,813 284,580 677,305 Sales for resale (a) 119,299 201,056 13,769 19,527 48,538 Other electric revenues (b) 94,125 90,529 30,977 8,511 25,733 Non-customer revenues (c) 5,312 10,081 4,873 2,802 850 Total electric revenues 1,045,629 2,066,795 669,432 315,420 752,426 Natural gas — 35,337 — 51,301 — Total operating revenues $1,045,629 $2,102,132 $669,432 $366,721 $752,426 (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 June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $770,373 $768,710 Commercial 595,025 581,899 Industrial 641,733 624,818 Governmental 57,623 56,823 Total billed retail 2,064,754 2,032,250 Sales for resale (a) 75,318 69,212 Other electric revenues (b) 195,952 219,391 Non-customer revenues (c) 9,703 9,372 Total electric revenues 2,345,727 2,330,225 Natural gas 30,699 29,943 Entergy Wholesale Commodities: Competitive businesses sales (a) 280,398 331,562 Non-customer revenues (c) 9,385 (22,960 ) Total competitive businesses 289,783 308,602 Total operating revenues $2,666,209 $2,668,770 Entergy’s total revenues for the six months ended June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,572,911 $1,660,795 Commercial 1,149,082 1,177,620 Industrial 1,242,734 1,222,004 Governmental 110,584 113,301 Total billed retail 4,075,311 4,173,720 Sales for resale (a) 159,753 138,738 Other electric revenues (b) 211,422 246,822 Non-customer revenues (c) 20,265 19,206 Total electric revenues 4,466,751 4,578,486 Natural gas 85,647 86,638 Entergy Wholesale Commodities: Competitive businesses sales (a) 640,869 740,697 Non-customer revenues (c) 82,525 (13,171 ) Total competitive businesses 723,394 727,526 Total operating revenues $5,275,792 $5,392,650 The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $157,714 $290,366 $116,801 $58,621 $146,871 Commercial 125,555 232,134 102,275 53,981 81,080 Industrial 118,913 384,919 38,739 8,490 90,672 Governmental 4,971 17,925 10,521 18,984 5,222 Total billed retail 407,153 925,344 268,336 140,076 323,845 Sales for resale (a) 74,501 83,208 4,994 8,579 14,772 Other electric revenues (b) 58,209 80,307 26,982 7,263 24,656 Non-customer revenues (c) 3,066 5,400 2,425 1,234 307 Total electric revenues 542,929 1,094,259 302,737 157,152 363,580 Natural gas — 12,058 — 18,641 — Total operating revenues $542,929 $1,106,317 $302,737 $175,793 $363,580 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $159,130 $267,915 $132,730 $58,232 $150,703 Commercial 93,741 221,740 117,351 54,524 94,544 Industrial 97,973 368,678 46,129 9,267 102,771 Governmental 3,766 16,705 11,452 18,448 6,452 Total billed retail 354,610 875,038 307,662 140,471 354,470 Sales for resale (a) 53,195 111,801 11,776 6,190 25,177 Other electric revenues (b) 84,102 70,027 31,696 11,623 23,468 Non-customer revenues (c) 2,698 4,823 2,555 1,318 371 Total electric revenues 494,605 1,061,689 353,689 159,602 403,486 Natural gas — 11,099 — 18,844 — Total operating revenues $494,605 $1,072,788 $353,689 $178,446 $403,486 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $367,581 $554,431 $245,610 $110,697 $294,592 Commercial 250,133 438,912 200,189 99,723 160,125 Industrial 240,491 731,598 76,436 15,740 178,470 Governmental 9,869 34,817 20,557 34,886 10,455 Total billed retail 868,074 1,759,758 542,792 261,046 643,642 Sales for resale (a) 154,085 167,164 9,808 18,803 31,548 Other electric revenues (b) 60,514 92,746 27,387 5,556 28,153 Non-customer revenues (c) 6,068 11,284 4,994 2,630 711 Total electric revenues 1,088,741 2,030,952 584,981 288,035 704,054 Natural gas — 34,695 — 50,952 — Total operating revenues $1,088,741 $2,065,647 $584,981 $338,987 $704,054 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $394,654 $563,433 $281,073 $122,807 $298,828 Commercial 214,375 446,667 227,811 108,796 179,971 Industrial 209,450 721,014 88,629 16,838 186,073 Governmental 8,414 34,015 22,300 36,139 12,433 Total billed retail 826,893 1,765,129 619,813 284,580 677,305 Sales for resale (a) 119,299 201,056 13,769 19,527 48,538 Other electric revenues (b) 94,125 90,529 30,977 8,511 25,733 Non-customer revenues (c) 5,312 10,081 4,873 2,802 850 Total electric revenues 1,045,629 2,066,795 669,432 315,420 752,426 Natural gas — 35,337 — 51,301 — Total operating revenues $1,045,629 $2,102,132 $669,432 $366,721 $752,426 (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 June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $770,373 $768,710 Commercial 595,025 581,899 Industrial 641,733 624,818 Governmental 57,623 56,823 Total billed retail 2,064,754 2,032,250 Sales for resale (a) 75,318 69,212 Other electric revenues (b) 195,952 219,391 Non-customer revenues (c) 9,703 9,372 Total electric revenues 2,345,727 2,330,225 Natural gas 30,699 29,943 Entergy Wholesale Commodities: Competitive businesses sales (a) 280,398 331,562 Non-customer revenues (c) 9,385 (22,960 ) Total competitive businesses 289,783 308,602 Total operating revenues $2,666,209 $2,668,770 Entergy’s total revenues for the six months ended June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,572,911 $1,660,795 Commercial 1,149,082 1,177,620 Industrial 1,242,734 1,222,004 Governmental 110,584 113,301 Total billed retail 4,075,311 4,173,720 Sales for resale (a) 159,753 138,738 Other electric revenues (b) 211,422 246,822 Non-customer revenues (c) 20,265 19,206 Total electric revenues 4,466,751 4,578,486 Natural gas 85,647 86,638 Entergy Wholesale Commodities: Competitive businesses sales (a) 640,869 740,697 Non-customer revenues (c) 82,525 (13,171 ) Total competitive businesses 723,394 727,526 Total operating revenues $5,275,792 $5,392,650 The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $157,714 $290,366 $116,801 $58,621 $146,871 Commercial 125,555 232,134 102,275 53,981 81,080 Industrial 118,913 384,919 38,739 8,490 90,672 Governmental 4,971 17,925 10,521 18,984 5,222 Total billed retail 407,153 925,344 268,336 140,076 323,845 Sales for resale (a) 74,501 83,208 4,994 8,579 14,772 Other electric revenues (b) 58,209 80,307 26,982 7,263 24,656 Non-customer revenues (c) 3,066 5,400 2,425 1,234 307 Total electric revenues 542,929 1,094,259 302,737 157,152 363,580 Natural gas — 12,058 — 18,641 — Total operating revenues $542,929 $1,106,317 $302,737 $175,793 $363,580 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $159,130 $267,915 $132,730 $58,232 $150,703 Commercial 93,741 221,740 117,351 54,524 94,544 Industrial 97,973 368,678 46,129 9,267 102,771 Governmental 3,766 16,705 11,452 18,448 6,452 Total billed retail 354,610 875,038 307,662 140,471 354,470 Sales for resale (a) 53,195 111,801 11,776 6,190 25,177 Other electric revenues (b) 84,102 70,027 31,696 11,623 23,468 Non-customer revenues (c) 2,698 4,823 2,555 1,318 371 Total electric revenues 494,605 1,061,689 353,689 159,602 403,486 Natural gas — 11,099 — 18,844 — Total operating revenues $494,605 $1,072,788 $353,689 $178,446 $403,486 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $367,581 $554,431 $245,610 $110,697 $294,592 Commercial 250,133 438,912 200,189 99,723 160,125 Industrial 240,491 731,598 76,436 15,740 178,470 Governmental 9,869 34,817 20,557 34,886 10,455 Total billed retail 868,074 1,759,758 542,792 261,046 643,642 Sales for resale (a) 154,085 167,164 9,808 18,803 31,548 Other electric revenues (b) 60,514 92,746 27,387 5,556 28,153 Non-customer revenues (c) 6,068 11,284 4,994 2,630 711 Total electric revenues 1,088,741 2,030,952 584,981 288,035 704,054 Natural gas — 34,695 — 50,952 — Total operating revenues $1,088,741 $2,065,647 $584,981 $338,987 $704,054 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $394,654 $563,433 $281,073 $122,807 $298,828 Commercial 214,375 446,667 227,811 108,796 179,971 Industrial 209,450 721,014 88,629 16,838 186,073 Governmental 8,414 34,015 22,300 36,139 12,433 Total billed retail 826,893 1,765,129 619,813 284,580 677,305 Sales for resale (a) 119,299 201,056 13,769 19,527 48,538 Other electric revenues (b) 94,125 90,529 30,977 8,511 25,733 Non-customer revenues (c) 5,312 10,081 4,873 2,802 850 Total electric revenues 1,045,629 2,066,795 669,432 315,420 752,426 Natural gas — 35,337 — 51,301 — Total operating revenues $1,045,629 $2,102,132 $669,432 $366,721 $752,426 (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 June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $770,373 $768,710 Commercial 595,025 581,899 Industrial 641,733 624,818 Governmental 57,623 56,823 Total billed retail 2,064,754 2,032,250 Sales for resale (a) 75,318 69,212 Other electric revenues (b) 195,952 219,391 Non-customer revenues (c) 9,703 9,372 Total electric revenues 2,345,727 2,330,225 Natural gas 30,699 29,943 Entergy Wholesale Commodities: Competitive businesses sales (a) 280,398 331,562 Non-customer revenues (c) 9,385 (22,960 ) Total competitive businesses 289,783 308,602 Total operating revenues $2,666,209 $2,668,770 Entergy’s total revenues for the six months ended June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,572,911 $1,660,795 Commercial 1,149,082 1,177,620 Industrial 1,242,734 1,222,004 Governmental 110,584 113,301 Total billed retail 4,075,311 4,173,720 Sales for resale (a) 159,753 138,738 Other electric revenues (b) 211,422 246,822 Non-customer revenues (c) 20,265 19,206 Total electric revenues 4,466,751 4,578,486 Natural gas 85,647 86,638 Entergy Wholesale Commodities: Competitive businesses sales (a) 640,869 740,697 Non-customer revenues (c) 82,525 (13,171 ) Total competitive businesses 723,394 727,526 Total operating revenues $5,275,792 $5,392,650 The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $157,714 $290,366 $116,801 $58,621 $146,871 Commercial 125,555 232,134 102,275 53,981 81,080 Industrial 118,913 384,919 38,739 8,490 90,672 Governmental 4,971 17,925 10,521 18,984 5,222 Total billed retail 407,153 925,344 268,336 140,076 323,845 Sales for resale (a) 74,501 83,208 4,994 8,579 14,772 Other electric revenues (b) 58,209 80,307 26,982 7,263 24,656 Non-customer revenues (c) 3,066 5,400 2,425 1,234 307 Total electric revenues 542,929 1,094,259 302,737 157,152 363,580 Natural gas — 12,058 — 18,641 — Total operating revenues $542,929 $1,106,317 $302,737 $175,793 $363,580 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $159,130 $267,915 $132,730 $58,232 $150,703 Commercial 93,741 221,740 117,351 54,524 94,544 Industrial 97,973 368,678 46,129 9,267 102,771 Governmental 3,766 16,705 11,452 18,448 6,452 Total billed retail 354,610 875,038 307,662 140,471 354,470 Sales for resale (a) 53,195 111,801 11,776 6,190 25,177 Other electric revenues (b) 84,102 70,027 31,696 11,623 23,468 Non-customer revenues (c) 2,698 4,823 2,555 1,318 371 Total electric revenues 494,605 1,061,689 353,689 159,602 403,486 Natural gas — 11,099 — 18,844 — Total operating revenues $494,605 $1,072,788 $353,689 $178,446 $403,486 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $367,581 $554,431 $245,610 $110,697 $294,592 Commercial 250,133 438,912 200,189 99,723 160,125 Industrial 240,491 731,598 76,436 15,740 178,470 Governmental 9,869 34,817 20,557 34,886 10,455 Total billed retail 868,074 1,759,758 542,792 261,046 643,642 Sales for resale (a) 154,085 167,164 9,808 18,803 31,548 Other electric revenues (b) 60,514 92,746 27,387 5,556 28,153 Non-customer revenues (c) 6,068 11,284 4,994 2,630 711 Total electric revenues 1,088,741 2,030,952 584,981 288,035 704,054 Natural gas — 34,695 — 50,952 — Total operating revenues $1,088,741 $2,065,647 $584,981 $338,987 $704,054 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $394,654 $563,433 $281,073 $122,807 $298,828 Commercial 214,375 446,667 227,811 108,796 179,971 Industrial 209,450 721,014 88,629 16,838 186,073 Governmental 8,414 34,015 22,300 36,139 12,433 Total billed retail 826,893 1,765,129 619,813 284,580 677,305 Sales for resale (a) 119,299 201,056 13,769 19,527 48,538 Other electric revenues (b) 94,125 90,529 30,977 8,511 25,733 Non-customer revenues (c) 5,312 10,081 4,873 2,802 850 Total electric revenues 1,045,629 2,066,795 669,432 315,420 752,426 Natural gas — 35,337 — 51,301 — Total operating revenues $1,045,629 $2,102,132 $669,432 $366,721 $752,426 (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 June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $770,373 $768,710 Commercial 595,025 581,899 Industrial 641,733 624,818 Governmental 57,623 56,823 Total billed retail 2,064,754 2,032,250 Sales for resale (a) 75,318 69,212 Other electric revenues (b) 195,952 219,391 Non-customer revenues (c) 9,703 9,372 Total electric revenues 2,345,727 2,330,225 Natural gas 30,699 29,943 Entergy Wholesale Commodities: Competitive businesses sales (a) 280,398 331,562 Non-customer revenues (c) 9,385 (22,960 ) Total competitive businesses 289,783 308,602 Total operating revenues $2,666,209 $2,668,770 Entergy’s total revenues for the six months ended June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,572,911 $1,660,795 Commercial 1,149,082 1,177,620 Industrial 1,242,734 1,222,004 Governmental 110,584 113,301 Total billed retail 4,075,311 4,173,720 Sales for resale (a) 159,753 138,738 Other electric revenues (b) 211,422 246,822 Non-customer revenues (c) 20,265 19,206 Total electric revenues 4,466,751 4,578,486 Natural gas 85,647 86,638 Entergy Wholesale Commodities: Competitive businesses sales (a) 640,869 740,697 Non-customer revenues (c) 82,525 (13,171 ) Total competitive businesses 723,394 727,526 Total operating revenues $5,275,792 $5,392,650 The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $157,714 $290,366 $116,801 $58,621 $146,871 Commercial 125,555 232,134 102,275 53,981 81,080 Industrial 118,913 384,919 38,739 8,490 90,672 Governmental 4,971 17,925 10,521 18,984 5,222 Total billed retail 407,153 925,344 268,336 140,076 323,845 Sales for resale (a) 74,501 83,208 4,994 8,579 14,772 Other electric revenues (b) 58,209 80,307 26,982 7,263 24,656 Non-customer revenues (c) 3,066 5,400 2,425 1,234 307 Total electric revenues 542,929 1,094,259 302,737 157,152 363,580 Natural gas — 12,058 — 18,641 — Total operating revenues $542,929 $1,106,317 $302,737 $175,793 $363,580 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $159,130 $267,915 $132,730 $58,232 $150,703 Commercial 93,741 221,740 117,351 54,524 94,544 Industrial 97,973 368,678 46,129 9,267 102,771 Governmental 3,766 16,705 11,452 18,448 6,452 Total billed retail 354,610 875,038 307,662 140,471 354,470 Sales for resale (a) 53,195 111,801 11,776 6,190 25,177 Other electric revenues (b) 84,102 70,027 31,696 11,623 23,468 Non-customer revenues (c) 2,698 4,823 2,555 1,318 371 Total electric revenues 494,605 1,061,689 353,689 159,602 403,486 Natural gas — 11,099 — 18,844 — Total operating revenues $494,605 $1,072,788 $353,689 $178,446 $403,486 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $367,581 $554,431 $245,610 $110,697 $294,592 Commercial 250,133 438,912 200,189 99,723 160,125 Industrial 240,491 731,598 76,436 15,740 178,470 Governmental 9,869 34,817 20,557 34,886 10,455 Total billed retail 868,074 1,759,758 542,792 261,046 643,642 Sales for resale (a) 154,085 167,164 9,808 18,803 31,548 Other electric revenues (b) 60,514 92,746 27,387 5,556 28,153 Non-customer revenues (c) 6,068 11,284 4,994 2,630 711 Total electric revenues 1,088,741 2,030,952 584,981 288,035 704,054 Natural gas — 34,695 — 50,952 — Total operating revenues $1,088,741 $2,065,647 $584,981 $338,987 $704,054 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $394,654 $563,433 $281,073 $122,807 $298,828 Commercial 214,375 446,667 227,811 108,796 179,971 Industrial 209,450 721,014 88,629 16,838 186,073 Governmental 8,414 34,015 22,300 36,139 12,433 Total billed retail 826,893 1,765,129 619,813 284,580 677,305 Sales for resale (a) 119,299 201,056 13,769 19,527 48,538 Other electric revenues (b) 94,125 90,529 30,977 8,511 25,733 Non-customer revenues (c) 5,312 10,081 4,873 2,802 850 Total electric revenues 1,045,629 2,066,795 669,432 315,420 752,426 Natural gas — 35,337 — 51,301 — Total operating revenues $1,045,629 $2,102,132 $669,432 $366,721 $752,426 (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 June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $770,373 $768,710 Commercial 595,025 581,899 Industrial 641,733 624,818 Governmental 57,623 56,823 Total billed retail 2,064,754 2,032,250 Sales for resale (a) 75,318 69,212 Other electric revenues (b) 195,952 219,391 Non-customer revenues (c) 9,703 9,372 Total electric revenues 2,345,727 2,330,225 Natural gas 30,699 29,943 Entergy Wholesale Commodities: Competitive businesses sales (a) 280,398 331,562 Non-customer revenues (c) 9,385 (22,960 ) Total competitive businesses 289,783 308,602 Total operating revenues $2,666,209 $2,668,770 Entergy’s total revenues for the six months ended June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,572,911 $1,660,795 Commercial 1,149,082 1,177,620 Industrial 1,242,734 1,222,004 Governmental 110,584 113,301 Total billed retail 4,075,311 4,173,720 Sales for resale (a) 159,753 138,738 Other electric revenues (b) 211,422 246,822 Non-customer revenues (c) 20,265 19,206 Total electric revenues 4,466,751 4,578,486 Natural gas 85,647 86,638 Entergy Wholesale Commodities: Competitive businesses sales (a) 640,869 740,697 Non-customer revenues (c) 82,525 (13,171 ) Total competitive businesses 723,394 727,526 Total operating revenues $5,275,792 $5,392,650 The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $157,714 $290,366 $116,801 $58,621 $146,871 Commercial 125,555 232,134 102,275 53,981 81,080 Industrial 118,913 384,919 38,739 8,490 90,672 Governmental 4,971 17,925 10,521 18,984 5,222 Total billed retail 407,153 925,344 268,336 140,076 323,845 Sales for resale (a) 74,501 83,208 4,994 8,579 14,772 Other electric revenues (b) 58,209 80,307 26,982 7,263 24,656 Non-customer revenues (c) 3,066 5,400 2,425 1,234 307 Total electric revenues 542,929 1,094,259 302,737 157,152 363,580 Natural gas — 12,058 — 18,641 — Total operating revenues $542,929 $1,106,317 $302,737 $175,793 $363,580 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $159,130 $267,915 $132,730 $58,232 $150,703 Commercial 93,741 221,740 117,351 54,524 94,544 Industrial 97,973 368,678 46,129 9,267 102,771 Governmental 3,766 16,705 11,452 18,448 6,452 Total billed retail 354,610 875,038 307,662 140,471 354,470 Sales for resale (a) 53,195 111,801 11,776 6,190 25,177 Other electric revenues (b) 84,102 70,027 31,696 11,623 23,468 Non-customer revenues (c) 2,698 4,823 2,555 1,318 371 Total electric revenues 494,605 1,061,689 353,689 159,602 403,486 Natural gas — 11,099 — 18,844 — Total operating revenues $494,605 $1,072,788 $353,689 $178,446 $403,486 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $367,581 $554,431 $245,610 $110,697 $294,592 Commercial 250,133 438,912 200,189 99,723 160,125 Industrial 240,491 731,598 76,436 15,740 178,470 Governmental 9,869 34,817 20,557 34,886 10,455 Total billed retail 868,074 1,759,758 542,792 261,046 643,642 Sales for resale (a) 154,085 167,164 9,808 18,803 31,548 Other electric revenues (b) 60,514 92,746 27,387 5,556 28,153 Non-customer revenues (c) 6,068 11,284 4,994 2,630 711 Total electric revenues 1,088,741 2,030,952 584,981 288,035 704,054 Natural gas — 34,695 — 50,952 — Total operating revenues $1,088,741 $2,065,647 $584,981 $338,987 $704,054 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $394,654 $563,433 $281,073 $122,807 $298,828 Commercial 214,375 446,667 227,811 108,796 179,971 Industrial 209,450 721,014 88,629 16,838 186,073 Governmental 8,414 34,015 22,300 36,139 12,433 Total billed retail 826,893 1,765,129 619,813 284,580 677,305 Sales for resale (a) 119,299 201,056 13,769 19,527 48,538 Other electric revenues (b) 94,125 90,529 30,977 8,511 25,733 Non-customer revenues (c) 5,312 10,081 4,873 2,802 850 Total electric revenues 1,045,629 2,066,795 669,432 315,420 752,426 Natural gas — 35,337 — 51,301 — Total operating revenues $1,045,629 $2,102,132 $669,432 $366,721 $752,426 (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	6 Months Ended
	Jun. 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	6 Months Ended
	Jun. 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 June 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 61 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 June 30, 2019: (In Thousands) Operating lease cost $15,255 Financing lease cost: Amortization of right-of-use assets $4,980 Interest on lease liabilities $1,081 Entergy incurred the following total lease costs for the six months ended June 30, 2019: (In Thousands) Operating lease cost $30,976 Financing lease cost: Amortization of right-of-use assets $7,892 Interest on lease liabilities $1,834 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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,124 $2,824 $1,716 $351 $977 Financing lease cost: Amortization of right-of-use assets $1,198 $1,975 $691 $342 $325 Interest on lease liabilities $198 $299 $117 $55 $53 The Registrant Subsidiaries incurred the following lease costs for the six months ended June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $6,419 $5,850 $3,468 $709 $2,062 Financing lease cost: Amortization of right-of-use assets $1,828 $3,000 $1,039 $518 $630 Interest on lease liabilities $303 $451 $176 $85 $99 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 June 30, 2019 are $234 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $48,567 $33,054 $18,791 $4,172 $12,540 Financing leases $11,167 $16,846 $6,671 $2,991 $5,439 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of June 30, 2019: (In Thousands) Current liabilities: Operating leases $51,885 Financing leases $11,177 Non-current liabilities: Operating leases $182,236 Financing leases $53,375 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,374 $9,727 $6,180 $1,218 $3,251 Financing leases $2,408 $3,840 $1,402 $662 $1,240 Non-current liabilities: Operating leases $38,195 $23,333 $12,812 $2,953 $9,375 Financing leases $8,756 $13,000 $5,269 $2,329 $4,112 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 June 30, 2019: Weighted average remaining lease terms: Operating leases 5.42 Financing leases 6.94 Weighted average discount rate: Operating leases 3.93 % Financing leases 4.71 % 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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.22 4.27 5.11 4.04 4.52 Financing leases 5.55 5.27 5.42 5.80 5.23 Weighted average discount rate: Operating leases 3.79 % 3.80 % 3.80 % 3.96 % 3.93 % Financing leases 3.78 % 3.78 % 3.77 % 3.95 % 3.89 % Maturity of the lease liabilities for Entergy as of June 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $30,913 $7,067 2020 57,615 13,052 2021 49,126 11,505 2022 40,519 10,307 2023 32,907 9,231 Years thereafter 53,491 25,696 Minimum lease payments 264,571 76,858 Less: amount representing interest 30,450 12,306 Present value of net minimum lease payments $234,121 $64,552 Maturity of the lease liabilities for the Registrant Subsidiaries as of June 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $6,070 $5,419 $3,580 $680 $1,924 2020 11,014 9,797 5,888 1,225 3,776 2021 9,117 8,046 4,759 954 3,026 2022 6,782 5,267 3,338 632 2,061 2023 5,619 3,391 1,237 470 1,704 Years thereafter 15,771 3,777 2,340 693 1,862 Minimum lease payments 54,373 35,697 21,142 4,654 14,353 Less: amount representing interest 5,804 2,637 2,150 483 1,726 Present value of net minimum lease payments $48,569 $33,060 $18,992 $4,171 $12,627 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $1,398 $2,235 $813 $403 $727 2020 2,560 4,032 1,549 645 1,297 2021 2,164 3,377 1,384 535 1,104 2022 1,875 2,937 1,191 484 897 2023 1,648 2,489 977 437 759 Years thereafter 2,698 3,453 1,444 834 1,111 Minimum lease payments 12,343 18,523 7,358 3,338 5,895 Less: amount representing interest 1,179 1,683 687 347 543 Present value of net minimum lease payments $11,164 $16,840 $6,671 $2,991 $5,352 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 June 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 61 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 June 30, 2019: (In Thousands) Operating lease cost $15,255 Financing lease cost: Amortization of right-of-use assets $4,980 Interest on lease liabilities $1,081 Entergy incurred the following total lease costs for the six months ended June 30, 2019: (In Thousands) Operating lease cost $30,976 Financing lease cost: Amortization of right-of-use assets $7,892 Interest on lease liabilities $1,834 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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,124 $2,824 $1,716 $351 $977 Financing lease cost: Amortization of right-of-use assets $1,198 $1,975 $691 $342 $325 Interest on lease liabilities $198 $299 $117 $55 $53 The Registrant Subsidiaries incurred the following lease costs for the six months ended June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $6,419 $5,850 $3,468 $709 $2,062 Financing lease cost: Amortization of right-of-use assets $1,828 $3,000 $1,039 $518 $630 Interest on lease liabilities $303 $451 $176 $85 $99 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 June 30, 2019 are $234 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $48,567 $33,054 $18,791 $4,172 $12,540 Financing leases $11,167 $16,846 $6,671 $2,991 $5,439 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of June 30, 2019: (In Thousands) Current liabilities: Operating leases $51,885 Financing leases $11,177 Non-current liabilities: Operating leases $182,236 Financing leases $53,375 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,374 $9,727 $6,180 $1,218 $3,251 Financing leases $2,408 $3,840 $1,402 $662 $1,240 Non-current liabilities: Operating leases $38,195 $23,333 $12,812 $2,953 $9,375 Financing leases $8,756 $13,000 $5,269 $2,329 $4,112 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 June 30, 2019: Weighted average remaining lease terms: Operating leases 5.42 Financing leases 6.94 Weighted average discount rate: Operating leases 3.93 % Financing leases 4.71 % 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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.22 4.27 5.11 4.04 4.52 Financing leases 5.55 5.27 5.42 5.80 5.23 Weighted average discount rate: Operating leases 3.79 % 3.80 % 3.80 % 3.96 % 3.93 % Financing leases 3.78 % 3.78 % 3.77 % 3.95 % 3.89 % Maturity of the lease liabilities for Entergy as of June 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $30,913 $7,067 2020 57,615 13,052 2021 49,126 11,505 2022 40,519 10,307 2023 32,907 9,231 Years thereafter 53,491 25,696 Minimum lease payments 264,571 76,858 Less: amount representing interest 30,450 12,306 Present value of net minimum lease payments $234,121 $64,552 Maturity of the lease liabilities for the Registrant Subsidiaries as of June 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $6,070 $5,419 $3,580 $680 $1,924 2020 11,014 9,797 5,888 1,225 3,776 2021 9,117 8,046 4,759 954 3,026 2022 6,782 5,267 3,338 632 2,061 2023 5,619 3,391 1,237 470 1,704 Years thereafter 15,771 3,777 2,340 693 1,862 Minimum lease payments 54,373 35,697 21,142 4,654 14,353 Less: amount representing interest 5,804 2,637 2,150 483 1,726 Present value of net minimum lease payments $48,569 $33,060 $18,992 $4,171 $12,627 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $1,398 $2,235 $813 $403 $727 2020 2,560 4,032 1,549 645 1,297 2021 2,164 3,377 1,384 535 1,104 2022 1,875 2,937 1,191 484 897 2023 1,648 2,489 977 437 759 Years thereafter 2,698 3,453 1,444 834 1,111 Minimum lease payments 12,343 18,523 7,358 3,338 5,895 Less: amount representing interest 1,179 1,683 687 347 543 Present value of net minimum lease payments $11,164 $16,840 $6,671 $2,991 $5,352 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 June 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 61 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 June 30, 2019: (In Thousands) Operating lease cost $15,255 Financing lease cost: Amortization of right-of-use assets $4,980 Interest on lease liabilities $1,081 Entergy incurred the following total lease costs for the six months ended June 30, 2019: (In Thousands) Operating lease cost $30,976 Financing lease cost: Amortization of right-of-use assets $7,892 Interest on lease liabilities $1,834 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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,124 $2,824 $1,716 $351 $977 Financing lease cost: Amortization of right-of-use assets $1,198 $1,975 $691 $342 $325 Interest on lease liabilities $198 $299 $117 $55 $53 The Registrant Subsidiaries incurred the following lease costs for the six months ended June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $6,419 $5,850 $3,468 $709 $2,062 Financing lease cost: Amortization of right-of-use assets $1,828 $3,000 $1,039 $518 $630 Interest on lease liabilities $303 $451 $176 $85 $99 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 June 30, 2019 are $234 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $48,567 $33,054 $18,791 $4,172 $12,540 Financing leases $11,167 $16,846 $6,671 $2,991 $5,439 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of June 30, 2019: (In Thousands) Current liabilities: Operating leases $51,885 Financing leases $11,177 Non-current liabilities: Operating leases $182,236 Financing leases $53,375 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,374 $9,727 $6,180 $1,218 $3,251 Financing leases $2,408 $3,840 $1,402 $662 $1,240 Non-current liabilities: Operating leases $38,195 $23,333 $12,812 $2,953 $9,375 Financing leases $8,756 $13,000 $5,269 $2,329 $4,112 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 June 30, 2019: Weighted average remaining lease terms: Operating leases 5.42 Financing leases 6.94 Weighted average discount rate: Operating leases 3.93 % Financing leases 4.71 % 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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.22 4.27 5.11 4.04 4.52 Financing leases 5.55 5.27 5.42 5.80 5.23 Weighted average discount rate: Operating leases 3.79 % 3.80 % 3.80 % 3.96 % 3.93 % Financing leases 3.78 % 3.78 % 3.77 % 3.95 % 3.89 % Maturity of the lease liabilities for Entergy as of June 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $30,913 $7,067 2020 57,615 13,052 2021 49,126 11,505 2022 40,519 10,307 2023 32,907 9,231 Years thereafter 53,491 25,696 Minimum lease payments 264,571 76,858 Less: amount representing interest 30,450 12,306 Present value of net minimum lease payments $234,121 $64,552 Maturity of the lease liabilities for the Registrant Subsidiaries as of June 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $6,070 $5,419 $3,580 $680 $1,924 2020 11,014 9,797 5,888 1,225 3,776 2021 9,117 8,046 4,759 954 3,026 2022 6,782 5,267 3,338 632 2,061 2023 5,619 3,391 1,237 470 1,704 Years thereafter 15,771 3,777 2,340 693 1,862 Minimum lease payments 54,373 35,697 21,142 4,654 14,353 Less: amount representing interest 5,804 2,637 2,150 483 1,726 Present value of net minimum lease payments $48,569 $33,060 $18,992 $4,171 $12,627 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $1,398 $2,235 $813 $403 $727 2020 2,560 4,032 1,549 645 1,297 2021 2,164 3,377 1,384 535 1,104 2022 1,875 2,937 1,191 484 897 2023 1,648 2,489 977 437 759 Years thereafter 2,698 3,453 1,444 834 1,111 Minimum lease payments 12,343 18,523 7,358 3,338 5,895 Less: amount representing interest 1,179 1,683 687 347 543 Present value of net minimum lease payments $11,164 $16,840 $6,671 $2,991 $5,352 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 June 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 61 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 June 30, 2019: (In Thousands) Operating lease cost $15,255 Financing lease cost: Amortization of right-of-use assets $4,980 Interest on lease liabilities $1,081 Entergy incurred the following total lease costs for the six months ended June 30, 2019: (In Thousands) Operating lease cost $30,976 Financing lease cost: Amortization of right-of-use assets $7,892 Interest on lease liabilities $1,834 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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,124 $2,824 $1,716 $351 $977 Financing lease cost: Amortization of right-of-use assets $1,198 $1,975 $691 $342 $325 Interest on lease liabilities $198 $299 $117 $55 $53 The Registrant Subsidiaries incurred the following lease costs for the six months ended June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $6,419 $5,850 $3,468 $709 $2,062 Financing lease cost: Amortization of right-of-use assets $1,828 $3,000 $1,039 $518 $630 Interest on lease liabilities $303 $451 $176 $85 $99 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 June 30, 2019 are $234 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $48,567 $33,054 $18,791 $4,172 $12,540 Financing leases $11,167 $16,846 $6,671 $2,991 $5,439 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of June 30, 2019: (In Thousands) Current liabilities: Operating leases $51,885 Financing leases $11,177 Non-current liabilities: Operating leases $182,236 Financing leases $53,375 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,374 $9,727 $6,180 $1,218 $3,251 Financing leases $2,408 $3,840 $1,402 $662 $1,240 Non-current liabilities: Operating leases $38,195 $23,333 $12,812 $2,953 $9,375 Financing leases $8,756 $13,000 $5,269 $2,329 $4,112 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 June 30, 2019: Weighted average remaining lease terms: Operating leases 5.42 Financing leases 6.94 Weighted average discount rate: Operating leases 3.93 % Financing leases 4.71 % 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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.22 4.27 5.11 4.04 4.52 Financing leases 5.55 5.27 5.42 5.80 5.23 Weighted average discount rate: Operating leases 3.79 % 3.80 % 3.80 % 3.96 % 3.93 % Financing leases 3.78 % 3.78 % 3.77 % 3.95 % 3.89 % Maturity of the lease liabilities for Entergy as of June 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $30,913 $7,067 2020 57,615 13,052 2021 49,126 11,505 2022 40,519 10,307 2023 32,907 9,231 Years thereafter 53,491 25,696 Minimum lease payments 264,571 76,858 Less: amount representing interest 30,450 12,306 Present value of net minimum lease payments $234,121 $64,552 Maturity of the lease liabilities for the Registrant Subsidiaries as of June 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $6,070 $5,419 $3,580 $680 $1,924 2020 11,014 9,797 5,888 1,225 3,776 2021 9,117 8,046 4,759 954 3,026 2022 6,782 5,267 3,338 632 2,061 2023 5,619 3,391 1,237 470 1,704 Years thereafter 15,771 3,777 2,340 693 1,862 Minimum lease payments 54,373 35,697 21,142 4,654 14,353 Less: amount representing interest 5,804 2,637 2,150 483 1,726 Present value of net minimum lease payments $48,569 $33,060 $18,992 $4,171 $12,627 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $1,398 $2,235 $813 $403 $727 2020 2,560 4,032 1,549 645 1,297 2021 2,164 3,377 1,384 535 1,104 2022 1,875 2,937 1,191 484 897 2023 1,648 2,489 977 437 759 Years thereafter 2,698 3,453 1,444 834 1,111 Minimum lease payments 12,343 18,523 7,358 3,338 5,895 Less: amount representing interest 1,179 1,683 687 347 543 Present value of net minimum lease payments $11,164 $16,840 $6,671 $2,991 $5,352 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 June 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 61 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 June 30, 2019: (In Thousands) Operating lease cost $15,255 Financing lease cost: Amortization of right-of-use assets $4,980 Interest on lease liabilities $1,081 Entergy incurred the following total lease costs for the six months ended June 30, 2019: (In Thousands) Operating lease cost $30,976 Financing lease cost: Amortization of right-of-use assets $7,892 Interest on lease liabilities $1,834 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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,124 $2,824 $1,716 $351 $977 Financing lease cost: Amortization of right-of-use assets $1,198 $1,975 $691 $342 $325 Interest on lease liabilities $198 $299 $117 $55 $53 The Registrant Subsidiaries incurred the following lease costs for the six months ended June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $6,419 $5,850 $3,468 $709 $2,062 Financing lease cost: Amortization of right-of-use assets $1,828 $3,000 $1,039 $518 $630 Interest on lease liabilities $303 $451 $176 $85 $99 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 June 30, 2019 are $234 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $48,567 $33,054 $18,791 $4,172 $12,540 Financing leases $11,167 $16,846 $6,671 $2,991 $5,439 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of June 30, 2019: (In Thousands) Current liabilities: Operating leases $51,885 Financing leases $11,177 Non-current liabilities: Operating leases $182,236 Financing leases $53,375 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,374 $9,727 $6,180 $1,218 $3,251 Financing leases $2,408 $3,840 $1,402 $662 $1,240 Non-current liabilities: Operating leases $38,195 $23,333 $12,812 $2,953 $9,375 Financing leases $8,756 $13,000 $5,269 $2,329 $4,112 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 June 30, 2019: Weighted average remaining lease terms: Operating leases 5.42 Financing leases 6.94 Weighted average discount rate: Operating leases 3.93 % Financing leases 4.71 % 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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.22 4.27 5.11 4.04 4.52 Financing leases 5.55 5.27 5.42 5.80 5.23 Weighted average discount rate: Operating leases 3.79 % 3.80 % 3.80 % 3.96 % 3.93 % Financing leases 3.78 % 3.78 % 3.77 % 3.95 % 3.89 % Maturity of the lease liabilities for Entergy as of June 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $30,913 $7,067 2020 57,615 13,052 2021 49,126 11,505 2022 40,519 10,307 2023 32,907 9,231 Years thereafter 53,491 25,696 Minimum lease payments 264,571 76,858 Less: amount representing interest 30,450 12,306 Present value of net minimum lease payments $234,121 $64,552 Maturity of the lease liabilities for the Registrant Subsidiaries as of June 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $6,070 $5,419 $3,580 $680 $1,924 2020 11,014 9,797 5,888 1,225 3,776 2021 9,117 8,046 4,759 954 3,026 2022 6,782 5,267 3,338 632 2,061 2023 5,619 3,391 1,237 470 1,704 Years thereafter 15,771 3,777 2,340 693 1,862 Minimum lease payments 54,373 35,697 21,142 4,654 14,353 Less: amount representing interest 5,804 2,637 2,150 483 1,726 Present value of net minimum lease payments $48,569 $33,060 $18,992 $4,171 $12,627 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $1,398 $2,235 $813 $403 $727 2020 2,560 4,032 1,549 645 1,297 2021 2,164 3,377 1,384 535 1,104 2022 1,875 2,937 1,191 484 897 2023 1,648 2,489 977 437 759 Years thereafter 2,698 3,453 1,444 834 1,111 Minimum lease payments 12,343 18,523 7,358 3,338 5,895 Less: amount representing interest 1,179 1,683 687 347 543 Present value of net minimum lease payments $11,164 $16,840 $6,671 $2,991 $5,352 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 June 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 61 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 June 30, 2019: (In Thousands) Operating lease cost $15,255 Financing lease cost: Amortization of right-of-use assets $4,980 Interest on lease liabilities $1,081 Entergy incurred the following total lease costs for the six months ended June 30, 2019: (In Thousands) Operating lease cost $30,976 Financing lease cost: Amortization of right-of-use assets $7,892 Interest on lease liabilities $1,834 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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,124 $2,824 $1,716 $351 $977 Financing lease cost: Amortization of right-of-use assets $1,198 $1,975 $691 $342 $325 Interest on lease liabilities $198 $299 $117 $55 $53 The Registrant Subsidiaries incurred the following lease costs for the six months ended June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $6,419 $5,850 $3,468 $709 $2,062 Financing lease cost: Amortization of right-of-use assets $1,828 $3,000 $1,039 $518 $630 Interest on lease liabilities $303 $451 $176 $85 $99 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 June 30, 2019 are $234 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $48,567 $33,054 $18,791 $4,172 $12,540 Financing leases $11,167 $16,846 $6,671 $2,991 $5,439 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of June 30, 2019: (In Thousands) Current liabilities: Operating leases $51,885 Financing leases $11,177 Non-current liabilities: Operating leases $182,236 Financing leases $53,375 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,374 $9,727 $6,180 $1,218 $3,251 Financing leases $2,408 $3,840 $1,402 $662 $1,240 Non-current liabilities: Operating leases $38,195 $23,333 $12,812 $2,953 $9,375 Financing leases $8,756 $13,000 $5,269 $2,329 $4,112 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 June 30, 2019: Weighted average remaining lease terms: Operating leases 5.42 Financing leases 6.94 Weighted average discount rate: Operating leases 3.93 % Financing leases 4.71 % 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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.22 4.27 5.11 4.04 4.52 Financing leases 5.55 5.27 5.42 5.80 5.23 Weighted average discount rate: Operating leases 3.79 % 3.80 % 3.80 % 3.96 % 3.93 % Financing leases 3.78 % 3.78 % 3.77 % 3.95 % 3.89 % Maturity of the lease liabilities for Entergy as of June 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $30,913 $7,067 2020 57,615 13,052 2021 49,126 11,505 2022 40,519 10,307 2023 32,907 9,231 Years thereafter 53,491 25,696 Minimum lease payments 264,571 76,858 Less: amount representing interest 30,450 12,306 Present value of net minimum lease payments $234,121 $64,552 Maturity of the lease liabilities for the Registrant Subsidiaries as of June 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $6,070 $5,419 $3,580 $680 $1,924 2020 11,014 9,797 5,888 1,225 3,776 2021 9,117 8,046 4,759 954 3,026 2022 6,782 5,267 3,338 632 2,061 2023 5,619 3,391 1,237 470 1,704 Years thereafter 15,771 3,777 2,340 693 1,862 Minimum lease payments 54,373 35,697 21,142 4,654 14,353 Less: amount representing interest 5,804 2,637 2,150 483 1,726 Present value of net minimum lease payments $48,569 $33,060 $18,992 $4,171 $12,627 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $1,398 $2,235 $813 $403 $727 2020 2,560 4,032 1,549 645 1,297 2021 2,164 3,377 1,384 535 1,104 2022 1,875 2,937 1,191 484 897 2023 1,648 2,489 977 437 759 Years thereafter 2,698 3,453 1,444 834 1,111 Minimum lease payments 12,343 18,523 7,358 3,338 5,895 Less: amount representing interest 1,179 1,683 687 347 543 Present value of net minimum lease payments $11,164 $16,840 $6,671 $2,991 $5,352 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 June 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 61 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 June 30, 2019: (In Thousands) Operating lease cost $15,255 Financing lease cost: Amortization of right-of-use assets $4,980 Interest on lease liabilities $1,081 Entergy incurred the following total lease costs for the six months ended June 30, 2019: (In Thousands) Operating lease cost $30,976 Financing lease cost: Amortization of right-of-use assets $7,892 Interest on lease liabilities $1,834 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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,124 $2,824 $1,716 $351 $977 Financing lease cost: Amortization of right-of-use assets $1,198 $1,975 $691 $342 $325 Interest on lease liabilities $198 $299 $117 $55 $53 The Registrant Subsidiaries incurred the following lease costs for the six months ended June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $6,419 $5,850 $3,468 $709 $2,062 Financing lease cost: Amortization of right-of-use assets $1,828 $3,000 $1,039 $518 $630 Interest on lease liabilities $303 $451 $176 $85 $99 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 June 30, 2019 are $234 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $48,567 $33,054 $18,791 $4,172 $12,540 Financing leases $11,167 $16,846 $6,671 $2,991 $5,439 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of June 30, 2019: (In Thousands) Current liabilities: Operating leases $51,885 Financing leases $11,177 Non-current liabilities: Operating leases $182,236 Financing leases $53,375 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,374 $9,727 $6,180 $1,218 $3,251 Financing leases $2,408 $3,840 $1,402 $662 $1,240 Non-current liabilities: Operating leases $38,195 $23,333 $12,812 $2,953 $9,375 Financing leases $8,756 $13,000 $5,269 $2,329 $4,112 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 June 30, 2019: Weighted average remaining lease terms: Operating leases 5.42 Financing leases 6.94 Weighted average discount rate: Operating leases 3.93 % Financing leases 4.71 % 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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.22 4.27 5.11 4.04 4.52 Financing leases 5.55 5.27 5.42 5.80 5.23 Weighted average discount rate: Operating leases 3.79 % 3.80 % 3.80 % 3.96 % 3.93 % Financing leases 3.78 % 3.78 % 3.77 % 3.95 % 3.89 % Maturity of the lease liabilities for Entergy as of June 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $30,913 $7,067 2020 57,615 13,052 2021 49,126 11,505 2022 40,519 10,307 2023 32,907 9,231 Years thereafter 53,491 25,696 Minimum lease payments 264,571 76,858 Less: amount representing interest 30,450 12,306 Present value of net minimum lease payments $234,121 $64,552 Maturity of the lease liabilities for the Registrant Subsidiaries as of June 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $6,070 $5,419 $3,580 $680 $1,924 2020 11,014 9,797 5,888 1,225 3,776 2021 9,117 8,046 4,759 954 3,026 2022 6,782 5,267 3,338 632 2,061 2023 5,619 3,391 1,237 470 1,704 Years thereafter 15,771 3,777 2,340 693 1,862 Minimum lease payments 54,373 35,697 21,142 4,654 14,353 Less: amount representing interest 5,804 2,637 2,150 483 1,726 Present value of net minimum lease payments $48,569 $33,060 $18,992 $4,171 $12,627 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $1,398 $2,235 $813 $403 $727 2020 2,560 4,032 1,549 645 1,297 2021 2,164 3,377 1,384 535 1,104 2022 1,875 2,937 1,191 484 897 2023 1,648 2,489 977 437 759 Years thereafter 2,698 3,453 1,444 834 1,111 Minimum lease payments 12,343 18,523 7,358 3,338 5,895 Less: amount representing interest 1,179 1,683 687 347 543 Present value of net minimum lease payments $11,164 $16,840 $6,671 $2,991 $5,352 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	6 Months Ended
	Jun. 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 after-tax) in the first quarter 2019.

Rate And Regulatory Matters Rat

Rate And Regulatory Matters Rate and Regulatory Matters (Tables)	6 Months Ended
	Jun. 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)	6 Months Ended
	Jun. 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 June 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 $236.4 193.0 $1.22 $245.4 180.8 $1.36 Average dilutive effect of: Stock options 0.5 — 0.3 — Other equity plans 0.7 — 0.7 (0.01 ) Equity forwards — — 1.2 (0.01 ) Diluted earnings per share $236.4 194.2 $1.22 $245.4 183.0 $1.34 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 June 30, 2018 . For the Six Months Ended June 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 $491.0 191.3 $2.57 $378.2 180.8 $2.09 Average dilutive effect of: Stock options 0.5 (0.01 ) 0.3 — Other equity plans 0.6 (0.01 ) 0.5 — Equity forwards 0.8 (0.01 ) 0.6 (0.01 ) Diluted earnings per share $491.0 193.2 $2.54 $378.2 182.2 $2.08
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 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, April 1, 2019 ($43,246 ) ($520,372 ) $12,466 ($551,152 ) Other comprehensive income (loss) before reclassifications 99,359 — 15,834 115,193 Amounts reclassified from accumulated other comprehensive income (loss) (4,377 ) 11,496 (1,564 ) 5,555 Net other comprehensive income (loss) for the period 94,982 11,496 14,270 120,748 Ending balance, June 30, 2019 $51,736 ($508,876 ) $26,736 ($430,404 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 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, April 1, 2018 $50,194 ($605,491 ) ($6,201 ) ($561,498 ) Other comprehensive income (loss) before reclassifications (62,981 ) — (7,509 ) (70,490 ) Amounts reclassified from accumulated other comprehensive income (loss) (2,087 ) 15,565 4,868 18,346 Net other comprehensive income (loss) for the period (65,068 ) 15,565 (2,641 ) (52,144 ) Ending balance, June 30, 2018 ($14,874 ) ($589,926 ) ($8,842 ) ($613,642 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 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 127,670 — 29,373 157,043 Amounts reclassified from accumulated other comprehensive income (loss) (45,114 ) 23,046 (1,400 ) (23,468 ) Net other comprehensive income (loss) for the period 82,556 23,046 27,973 133,575 Ending balance, June 30, 2019 $51,736 ($508,876 ) $26,736 ($430,404 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 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 8,585 — (43,785 ) (35,200 ) Amounts reclassified from accumulated other comprehensive income (loss) 21,774 32,139 8,288 62,201 Net other comprehensive income (loss) for the period 30,359 32,139 (35,497 ) 27,001 Reclassification pursuant to ASU 2018-02 (7,756 ) (90,966 ) 114,227 15,505 Ending balance, June 30, 2018 ($14,874 ) ($589,926 ) ($8,842 ) ($613,642 )
Reclassification out of Accumulated Other Comprehensive Income	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended June 30, 2019 and 2018 are as follows: Amounts reclassified Income Statement Location 2019 2018 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $5,589 $2,735 Competitive business operating revenues Interest rate swaps (48 ) (93 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 5,541 2,642 (1,164 ) (555 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $4,377 $2,087 Pension and other postretirement liabilities Amortization of prior-service credit $5,325 $5,424 (a) Amortization of loss (18,980 ) (24,808 ) (a) Settlement loss (918 ) (406 ) (a) Total amortization (14,573 ) (19,790 ) 3,077 4,225 Income taxes Total amortization (net of tax) ($11,496 ) ($15,565 ) Net unrealized investment gain (loss) Realized gain (loss) $2,475 ($7,702 ) Interest and investment income (911 ) 2,834 Income taxes Total realized investment gain (loss) (net of tax) $1,564 ($4,868 ) Total reclassifications for the period (net of tax) ($5,555 ) ($18,346 ) (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 six months ended June 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 $57,204 ($27,347 ) Competitive business operating revenues Interest rate swaps (97 ) (215 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 57,107 (27,562 ) (11,993 ) 5,788 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $45,114 ($21,774 ) Pension and other postretirement liabilities Amortization of prior-service credit $10,652 $10,850 (a) Amortization of loss (37,969 ) (49,760 ) (a) Settlement loss (2,055 ) (2,022 ) (a) Total amortization (29,372 ) (40,932 ) 6,326 8,793 Income taxes Total amortization (net of tax) ($23,046 ) ($32,139 ) Net unrealized investment gain (loss) Realized gain (loss) $2,216 ($13,114 ) Interest and investment income (816 ) 4,826 Income taxes Total realized investment gain (loss) (net of tax) $1,400 ($8,288 ) Total reclassifications for the period (net of tax) $23,468 ($62,201 ) (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 June 30, 2019 and 2018: Pension and Other 2019 2018 (In Thousands) Beginning balance, April 1, ($7,122 ) ($56,950 ) Amounts reclassified from accumulated other (969 ) (501 ) Net other comprehensive income (loss) for the period (969 ) (501 ) Ending balance, June 30, ($8,091 ) ($57,451 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2019 and 2018: Pension and Other 2019 2018 (In Thousands) Beginning balance, January 1, ($6,153 ) ($46,400 ) Amounts reclassified from accumulated other (1,938 ) (1,002 ) Net other comprehensive income (loss) for the period (1,938 ) (1,002 ) Reclassification pursuant to ASU 2018-02 — (10,049 ) Ending balance, June 30, ($8,091 ) ($57,451 )
Reclassification out of Accumulated Other Comprehensive Income	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended June 30, 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 ) (1,256 ) (a) Total amortization 1,311 678 (342 ) (177 ) Income taxes Total amortization (net of tax) 969 501 Total reclassifications for the period (net of tax) $969 $501 (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 six months ended June 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 $3,674 $3,868 (a) Amortization of loss (1,052 ) (2,513 ) (a) Total amortization 2,622 1,355 (684 ) (353 ) Income taxes Total amortization (net of tax) 1,938 1,002 Total reclassifications for the period (net of tax) $1,938 $1,002 (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)	6 Months Ended
	Jun. 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 June 30, 2019 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $150 $6 $3,344
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2019 Letters of Credit Outstanding as of June 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.57% $— $— Entergy Arkansas September 2023 $150 million (c) 3.57% $— $— Entergy Louisiana September 2023 $350 million (c) 3.57% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.82% $— $— Entergy Mississippi May 2020 $35 million (d) 3.82% $— $— Entergy Mississippi May 2020 $10 million (d) 3.82% $— $— Entergy New Orleans November 2021 $25 million (c) 3.59% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.82% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 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 June 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $37.8 million Entergy Mississippi $40 million 0.70% $10.9 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $29.5 million (a) As of June 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 $36 Entergy Texas $200 $169 System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of June 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.40% $20.6 Entergy Louisiana River Bend VIE September 2021 $105 3.40% $87.5 Entergy Louisiana Waterford VIE September 2021 $105 3.40% $79.2 System Energy VIE September 2021 $120 3.40% $74.4 (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 June 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 June 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,354,298 $18,126,143 Entergy Arkansas $3,527,146 $3,523,519 Entergy Louisiana $7,359,935 $7,892,133 Entergy Mississippi $1,619,420 $1,680,869 Entergy New Orleans $478,514 $511,691 Entergy Texas $1,664,936 $1,786,350 System Energy $590,646 $571,693 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $189 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 June 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2019 Letters of Credit Outstanding as of June 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.57% $— $— Entergy Arkansas September 2023 $150 million (c) 3.57% $— $— Entergy Louisiana September 2023 $350 million (c) 3.57% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.82% $— $— Entergy Mississippi May 2020 $35 million (d) 3.82% $— $— Entergy Mississippi May 2020 $10 million (d) 3.82% $— $— Entergy New Orleans November 2021 $25 million (c) 3.59% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.82% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 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 June 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $37.8 million Entergy Mississippi $40 million 0.70% $10.9 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $29.5 million (a) As of June 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 $36 Entergy Texas $200 $169 System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of June 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.40% $20.6 Entergy Louisiana River Bend VIE September 2021 $105 3.40% $87.5 Entergy Louisiana Waterford VIE September 2021 $105 3.40% $79.2 System Energy VIE September 2021 $120 3.40% $74.4 (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 June 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 June 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,354,298 $18,126,143 Entergy Arkansas $3,527,146 $3,523,519 Entergy Louisiana $7,359,935 $7,892,133 Entergy Mississippi $1,619,420 $1,680,869 Entergy New Orleans $478,514 $511,691 Entergy Texas $1,664,936 $1,786,350 System Energy $590,646 $571,693 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $189 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 June 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2019 Letters of Credit Outstanding as of June 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.57% $— $— Entergy Arkansas September 2023 $150 million (c) 3.57% $— $— Entergy Louisiana September 2023 $350 million (c) 3.57% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.82% $— $— Entergy Mississippi May 2020 $35 million (d) 3.82% $— $— Entergy Mississippi May 2020 $10 million (d) 3.82% $— $— Entergy New Orleans November 2021 $25 million (c) 3.59% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.82% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 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 June 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $37.8 million Entergy Mississippi $40 million 0.70% $10.9 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $29.5 million (a) As of June 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 $36 Entergy Texas $200 $169 System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of June 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.40% $20.6 Entergy Louisiana River Bend VIE September 2021 $105 3.40% $87.5 Entergy Louisiana Waterford VIE September 2021 $105 3.40% $79.2 System Energy VIE September 2021 $120 3.40% $74.4 (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 June 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 June 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,354,298 $18,126,143 Entergy Arkansas $3,527,146 $3,523,519 Entergy Louisiana $7,359,935 $7,892,133 Entergy Mississippi $1,619,420 $1,680,869 Entergy New Orleans $478,514 $511,691 Entergy Texas $1,664,936 $1,786,350 System Energy $590,646 $571,693 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $189 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 June 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2019 Letters of Credit Outstanding as of June 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.57% $— $— Entergy Arkansas September 2023 $150 million (c) 3.57% $— $— Entergy Louisiana September 2023 $350 million (c) 3.57% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.82% $— $— Entergy Mississippi May 2020 $35 million (d) 3.82% $— $— Entergy Mississippi May 2020 $10 million (d) 3.82% $— $— Entergy New Orleans November 2021 $25 million (c) 3.59% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.82% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 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 June 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $37.8 million Entergy Mississippi $40 million 0.70% $10.9 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $29.5 million (a) As of June 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 $36 Entergy Texas $200 $169 System Energy $200 $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,354,298 $18,126,143 Entergy Arkansas $3,527,146 $3,523,519 Entergy Louisiana $7,359,935 $7,892,133 Entergy Mississippi $1,619,420 $1,680,869 Entergy New Orleans $478,514 $511,691 Entergy Texas $1,664,936 $1,786,350 System Energy $590,646 $571,693 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $189 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 June 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2019 Letters of Credit Outstanding as of June 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.57% $— $— Entergy Arkansas September 2023 $150 million (c) 3.57% $— $— Entergy Louisiana September 2023 $350 million (c) 3.57% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.82% $— $— Entergy Mississippi May 2020 $35 million (d) 3.82% $— $— Entergy Mississippi May 2020 $10 million (d) 3.82% $— $— Entergy New Orleans November 2021 $25 million (c) 3.59% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.82% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 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 June 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $37.8 million Entergy Mississippi $40 million 0.70% $10.9 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $29.5 million (a) As of June 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 $36 Entergy Texas $200 $169 System Energy $200 $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,354,298 $18,126,143 Entergy Arkansas $3,527,146 $3,523,519 Entergy Louisiana $7,359,935 $7,892,133 Entergy Mississippi $1,619,420 $1,680,869 Entergy New Orleans $478,514 $511,691 Entergy Texas $1,664,936 $1,786,350 System Energy $590,646 $571,693 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $189 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 June 30, 2019 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2019 Letters of Credit Outstanding as of June 30, 2019 Entergy Arkansas April 2020 $20 million (b) 3.57% $— $— Entergy Arkansas September 2023 $150 million (c) 3.57% $— $— Entergy Louisiana September 2023 $350 million (c) 3.57% $— $— Entergy Mississippi May 2020 $37.5 million (d) 3.82% $— $— Entergy Mississippi May 2020 $35 million (d) 3.82% $— $— Entergy Mississippi May 2020 $10 million (d) 3.82% $— $— Entergy New Orleans November 2021 $25 million (c) 3.59% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.82% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 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 June 30, 2019 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2019 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $37.8 million Entergy Mississippi $40 million 0.70% $10.9 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $29.5 million (a) As of June 30, 2019 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 $36 Entergy Texas $200 $169 System Energy $200 $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,354,298 $18,126,143 Entergy Arkansas $3,527,146 $3,523,519 Entergy Louisiana $7,359,935 $7,892,133 Entergy Mississippi $1,619,420 $1,680,869 Entergy New Orleans $478,514 $511,691 Entergy Texas $1,664,936 $1,786,350 System Energy $590,646 $571,693 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $189 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 June 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 $36 Entergy Texas $200 $169 System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of June 30, 2019 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2019 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.40% $20.6 Entergy Louisiana River Bend VIE September 2021 $105 3.40% $87.5 Entergy Louisiana Waterford VIE September 2021 $105 3.40% $79.2 System Energy VIE September 2021 $120 3.40% $74.4 (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 June 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 June 30, 2019 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $17,354,298 $18,126,143 Entergy Arkansas $3,527,146 $3,523,519 Entergy Louisiana $7,359,935 $7,892,133 Entergy Mississippi $1,619,420 $1,680,869 Entergy New Orleans $478,514 $511,691 Entergy Texas $1,664,936 $1,786,350 System Energy $590,646 $571,693 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $189 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]	6 Months Ended
	Jun. 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 June 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $1.0 $1.1 Tax benefit recognized in Entergy’s net income $0.3 $0.3 Compensation cost capitalized as part of fixed assets and materials and supplies $0.3 $0.2 The following table includes financial information for outstanding stock options for the six months ended June 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $2.0 $2.2 Tax benefit recognized in Entergy’s net income $0.5 $0.6 Compensation cost capitalized as part of fixed assets and materials and supplies $0.6 $0.4
Financial Information For Restricted Stock	The following table includes financial information for other outstanding equity awards for the three months ended June 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $8.4 $8.7 Tax benefit recognized in Entergy’s net income $2.2 $2.2 Compensation cost capitalized as part of fixed assets and materials and supplies $2.9 $2.5 The following table includes financial information for other outstanding equity awards for the six months ended June 30, 2019 and 2018 : 2019 2018 (In Millions) Compensation expense included in Entergy’s net income $17.2 $17.5 Tax benefit recognized in Entergy’s net income $4.4 $4.4 Compensation cost capitalized as part of fixed assets and materials and supplies $5.8 $4.8

Retirement And Other Postreti_2

Retirement And Other Postretirement Benefits (Tables)	6 Months Ended
	Jun. 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 second 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) (18,736 ) 308 (552 ) (18,980 ) Settlement loss (162 ) — (756 ) (918 ) ($18,898 ) $5,683 ($1,358 ) ($14,573 ) 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 ) $5,594 ($71 ) $5,424 Amortization of net loss (21,957 ) (1,933 ) (918 ) (24,808 ) Settlement loss — — (406 ) (406 ) ($22,056 ) $3,661 ($1,395 ) ($19,790 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (387 ) (2 ) (1,256 ) ($867 ) $1,547 ($2 ) $678 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,750 ($98 ) $10,652 Amortization of net gain (loss) (37,470 ) 615 (1,114 ) (37,969 ) Settlement loss (1,299 ) — (756 ) (2,055 ) ($38,769 ) $11,365 ($1,968 ) ($29,372 ) Entergy Louisiana Amortization of prior service credit $— $3,674 $— $3,674 Amortization of net gain (loss) (1,397 ) 348 (3 ) (1,052 ) ($1,397 ) $4,022 ($3 ) $2,622 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($198 ) $11,189 ($141 ) $10,850 Amortization of net loss (43,914 ) (3,865 ) (1,981 ) (49,760 ) Settlement loss — — (2,022 ) (2,022 ) ($44,112 ) $7,324 ($4,144 ) ($40,932 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of net loss (1,734 ) (775 ) (4 ) (2,513 ) ($1,734 ) $3,093 ($4 ) $1,355
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $33,606 $38,752 Interest cost on projected benefit obligation 73,912 66,854 Expected return on assets (103,859 ) (110,535 ) Amortization of prior service cost — 99 Amortization of net loss 58,420 68,526 Settlement charges 162 — Net pension costs $62,241 $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $67,213 $77,504 Interest cost on projected benefit obligation 147,853 133,708 Expected return on assets (207,743 ) (221,070 ) Amortization of prior service cost — 198 Amortization of net loss 116,838 137,052 Settlement charges 1,299 — Net pension costs $125,460 $127,392
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Entergy’s other postretirement benefit cost, including amounts capitalized, for the second 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, including amounts capitalized, for the six months ended June 30, 2019 and 2018, included the following components: 2019 2018 (In Thousands) Service cost - benefits earned during the period $9,350 $13,564 Interest cost on accumulated postretirement benefit obligation (APBO) 23,950 25,362 Expected return on assets (19,124 ) (20,746 ) Amortization of prior service credit (17,688 ) (18,502 ) Amortization of net loss 716 6,864 Net other postretirement benefit cost (income) ($2,796 ) $6,542
Entergy Arkansas [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,261 $7,284 $1,629 $569 $1,350 $1,550 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,874 3,612 3,363 Expected return on assets (20,176 ) (22,652 ) (5,968 ) (2,697 ) (5,862 ) (4,677 ) Amortization of net loss 11,841 11,643 3,105 1,530 2,334 2,850 Net pension cost $11,101 $12,157 $2,834 $1,276 $1,434 $3,086 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 six months ended June 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 $10,522 $14,568 $3,258 $1,138 $2,700 $3,100 Interest cost on projected benefit obligation 28,350 31,764 8,136 3,748 7,224 6,727 Expected return on assets (40,352 ) (45,304 ) (11,936 ) (5,393 ) (11,724 ) (9,354 ) Amortization of net loss 23,682 23,286 6,209 3,059 4,668 5,700 Net pension cost $22,202 $24,314 $5,667 $2,552 $2,868 $6,173 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $12,378 $16,892 $3,644 $1,346 $3,178 $3,552 Interest cost on projected benefit obligation 26,008 29,880 7,538 3,626 6,696 6,454 Expected return on assets (43,702 ) (49,618 ) (13,004 ) (5,986 ) (13,046 ) (9,982 ) Amortization of net loss 26,824 28,900 7,220 3,908 5,252 7,430 Net pension cost $21,508 $26,054 $5,398 $2,894 $2,080 $7,454
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 June 2019 $9,338 $10,093 $2,671 $674 $739 $2,944 Remaining estimated pension contributions to be made in 2019 $17,774 $16,358 $5,030 $1,126 $906 $5,341
Entergy Arkansas [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for second 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, including amounts capitalized, for their employees for the six months ended June 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 $1,182 $2,320 $524 $184 $472 $486 Interest cost on APBO 3,614 5,332 1,340 790 1,708 952 Expected return on assets (7,982 ) — (2,398 ) (2,474 ) (4,552 ) (1,394 ) Amortization of prior service credit (2,476 ) (3,674 ) (878 ) (342 ) (1,122 ) (726 ) Amortization of net (gain) loss 288 (348 ) 362 116 242 178 Net other postretirement benefit cost (income) ($5,374 ) $3,630 ($1,050 ) ($1,726 ) ($3,252 ) ($504 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,586 $3,112 $642 $258 $660 $612 Interest cost on APBO 3,994 5,578 1,366 834 1,878 1,000 Expected return on assets (8,684 ) — (2,606 ) (2,626 ) (4,892 ) (1,566 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of net loss 578 776 754 68 412 466 Net other postretirement benefit cost (income) ($5,082 ) $5,598 ($756 ) ($1,838 ) ($3,100 ) ($244 )
Entergy Arkansas [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $71 $41 $113 $6 $122 2018 $122 $46 $77 $21 $270 Reflected in Entergy Mississippi’s non-qualified pension costs in the second quarter of 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 in the second quarter of 2018 were settlement charges of $10 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs in the second quarter of 2018 were settlement charges of $139 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 six months ended June 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $144 $84 $188 $11 $246 2018 $254 $96 $157 $42 $407 Reflected in Entergy Mississippi’s non-qualified pension costs for the six months ended June 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 six months ended June 30, 2018 were settlement charges of $22 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the six months ended June 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 second 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) (18,736 ) 308 (552 ) (18,980 ) Settlement loss (162 ) — (756 ) (918 ) ($18,898 ) $5,683 ($1,358 ) ($14,573 ) 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 ) $5,594 ($71 ) $5,424 Amortization of net loss (21,957 ) (1,933 ) (918 ) (24,808 ) Settlement loss — — (406 ) (406 ) ($22,056 ) $3,661 ($1,395 ) ($19,790 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (387 ) (2 ) (1,256 ) ($867 ) $1,547 ($2 ) $678 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2019 and 2018: 2019 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,750 ($98 ) $10,652 Amortization of net gain (loss) (37,470 ) 615 (1,114 ) (37,969 ) Settlement loss (1,299 ) — (756 ) (2,055 ) ($38,769 ) $11,365 ($1,968 ) ($29,372 ) Entergy Louisiana Amortization of prior service credit $— $3,674 $— $3,674 Amortization of net gain (loss) (1,397 ) 348 (3 ) (1,052 ) ($1,397 ) $4,022 ($3 ) $2,622 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit ($198 ) $11,189 ($141 ) $10,850 Amortization of net loss (43,914 ) (3,865 ) (1,981 ) (49,760 ) Settlement loss — — (2,022 ) (2,022 ) ($44,112 ) $7,324 ($4,144 ) ($40,932 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of net loss (1,734 ) (775 ) (4 ) (2,513 ) ($1,734 ) $3,093 ($4 ) $1,355
Entergy Louisiana [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2019 and 2018, included the following components: 2019 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,261 $7,284 $1,629 $569 $1,350 $1,550 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,874 3,612 3,363 Expected return on assets (20,176 ) (22,652 ) (5,968 ) (2,697 ) (5,862 ) (4,677 ) Amortization of net loss 11,841 11,643 3,105 1,530 2,334 2,850 Net pension cost $11,101 $12,157 $2,834 $1,276 $1,434 $3,086 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 six months ended June 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 $10,522 $14,568 $3,258 $1,138 $2,700 $3,100 Interest cost on projected benefit obligation 28,350 31,764 8,136 3,748 7,224 6,727 Expected return on assets (40,352 ) (45,304 ) (11,936 ) (5,393 ) (11,724 ) (9,354 ) Amortization of net loss 23,682 23,286 6,209 3,059 4,668 5,700 Net pension cost $22,202 $24,314 $5,667 $2,552 $2,868 $6,173 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $12,378 $16,892 $3,644 $1,346 $3,178 $3,552 Interest cost on projected benefit obligation 26,008 29,880 7,538 3,626 6,696 6,454 Expected return on assets (43,702 ) (49,618 ) (13,004 ) (5,986 ) (13,046 ) (9,982 ) Amortization of net loss 26,824 28,900 7,220 3,908 5,252 7,430 Net pension cost $21,508 $26,054 $5,398 $2,894 $2,080 $7,454
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 June 2019 $9,338 $10,093 $2,671 $674 $739 $2,944 Remaining estimated pension contributions to be made in 2019 $17,774 $16,358 $5,030 $1,126 $906 $5,341
Entergy Louisiana [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for second 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, including amounts capitalized, for their employees for the six months ended June 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 $1,182 $2,320 $524 $184 $472 $486 Interest cost on APBO 3,614 5,332 1,340 790 1,708 952 Expected return on assets (7,982 ) — (2,398 ) (2,474 ) (4,552 ) (1,394 ) Amortization of prior service credit (2,476 ) (3,674 ) (878 ) (342 ) (1,122 ) (726 ) Amortization of net (gain) loss 288 (348 ) 362 116 242 178 Net other postretirement benefit cost (income) ($5,374 ) $3,630 ($1,050 ) ($1,726 ) ($3,252 ) ($504 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,586 $3,112 $642 $258 $660 $612 Interest cost on APBO 3,994 5,578 1,366 834 1,878 1,000 Expected return on assets (8,684 ) — (2,606 ) (2,626 ) (4,892 ) (1,566 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of net loss 578 776 754 68 412 466 Net other postretirement benefit cost (income) ($5,082 ) $5,598 ($756 ) ($1,838 ) ($3,100 ) ($244 )
Entergy Louisiana [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $71 $41 $113 $6 $122 2018 $122 $46 $77 $21 $270 Reflected in Entergy Mississippi’s non-qualified pension costs in the second quarter of 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 in the second quarter of 2018 were settlement charges of $10 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs in the second quarter of 2018 were settlement charges of $139 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 six months ended June 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $144 $84 $188 $11 $246 2018 $254 $96 $157 $42 $407 Reflected in Entergy Mississippi’s non-qualified pension costs for the six months ended June 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 six months ended June 30, 2018 were settlement charges of $22 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the six months ended June 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 second 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 $5,261 $7,284 $1,629 $569 $1,350 $1,550 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,874 3,612 3,363 Expected return on assets (20,176 ) (22,652 ) (5,968 ) (2,697 ) (5,862 ) (4,677 ) Amortization of net loss 11,841 11,643 3,105 1,530 2,334 2,850 Net pension cost $11,101 $12,157 $2,834 $1,276 $1,434 $3,086 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 six months ended June 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 $10,522 $14,568 $3,258 $1,138 $2,700 $3,100 Interest cost on projected benefit obligation 28,350 31,764 8,136 3,748 7,224 6,727 Expected return on assets (40,352 ) (45,304 ) (11,936 ) (5,393 ) (11,724 ) (9,354 ) Amortization of net loss 23,682 23,286 6,209 3,059 4,668 5,700 Net pension cost $22,202 $24,314 $5,667 $2,552 $2,868 $6,173 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $12,378 $16,892 $3,644 $1,346 $3,178 $3,552 Interest cost on projected benefit obligation 26,008 29,880 7,538 3,626 6,696 6,454 Expected return on assets (43,702 ) (49,618 ) (13,004 ) (5,986 ) (13,046 ) (9,982 ) Amortization of net loss 26,824 28,900 7,220 3,908 5,252 7,430 Net pension cost $21,508 $26,054 $5,398 $2,894 $2,080 $7,454
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 June 2019 $9,338 $10,093 $2,671 $674 $739 $2,944 Remaining estimated pension contributions to be made in 2019 $17,774 $16,358 $5,030 $1,126 $906 $5,341
Entergy Mississippi [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for second 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, including amounts capitalized, for their employees for the six months ended June 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 $1,182 $2,320 $524 $184 $472 $486 Interest cost on APBO 3,614 5,332 1,340 790 1,708 952 Expected return on assets (7,982 ) — (2,398 ) (2,474 ) (4,552 ) (1,394 ) Amortization of prior service credit (2,476 ) (3,674 ) (878 ) (342 ) (1,122 ) (726 ) Amortization of net (gain) loss 288 (348 ) 362 116 242 178 Net other postretirement benefit cost (income) ($5,374 ) $3,630 ($1,050 ) ($1,726 ) ($3,252 ) ($504 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,586 $3,112 $642 $258 $660 $612 Interest cost on APBO 3,994 5,578 1,366 834 1,878 1,000 Expected return on assets (8,684 ) — (2,606 ) (2,626 ) (4,892 ) (1,566 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of net loss 578 776 754 68 412 466 Net other postretirement benefit cost (income) ($5,082 ) $5,598 ($756 ) ($1,838 ) ($3,100 ) ($244 )
Entergy Mississippi [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $71 $41 $113 $6 $122 2018 $122 $46 $77 $21 $270 Reflected in Entergy Mississippi’s non-qualified pension costs in the second quarter of 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 in the second quarter of 2018 were settlement charges of $10 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs in the second quarter of 2018 were settlement charges of $139 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 six months ended June 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $144 $84 $188 $11 $246 2018 $254 $96 $157 $42 $407 Reflected in Entergy Mississippi’s non-qualified pension costs for the six months ended June 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 six months ended June 30, 2018 were settlement charges of $22 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the six months ended June 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 second 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 $5,261 $7,284 $1,629 $569 $1,350 $1,550 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,874 3,612 3,363 Expected return on assets (20,176 ) (22,652 ) (5,968 ) (2,697 ) (5,862 ) (4,677 ) Amortization of net loss 11,841 11,643 3,105 1,530 2,334 2,850 Net pension cost $11,101 $12,157 $2,834 $1,276 $1,434 $3,086 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 six months ended June 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 $10,522 $14,568 $3,258 $1,138 $2,700 $3,100 Interest cost on projected benefit obligation 28,350 31,764 8,136 3,748 7,224 6,727 Expected return on assets (40,352 ) (45,304 ) (11,936 ) (5,393 ) (11,724 ) (9,354 ) Amortization of net loss 23,682 23,286 6,209 3,059 4,668 5,700 Net pension cost $22,202 $24,314 $5,667 $2,552 $2,868 $6,173 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $12,378 $16,892 $3,644 $1,346 $3,178 $3,552 Interest cost on projected benefit obligation 26,008 29,880 7,538 3,626 6,696 6,454 Expected return on assets (43,702 ) (49,618 ) (13,004 ) (5,986 ) (13,046 ) (9,982 ) Amortization of net loss 26,824 28,900 7,220 3,908 5,252 7,430 Net pension cost $21,508 $26,054 $5,398 $2,894 $2,080 $7,454
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 June 2019 $9,338 $10,093 $2,671 $674 $739 $2,944 Remaining estimated pension contributions to be made in 2019 $17,774 $16,358 $5,030 $1,126 $906 $5,341
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, including amounts capitalized, for their employees for second 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, including amounts capitalized, for their employees for the six months ended June 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 $1,182 $2,320 $524 $184 $472 $486 Interest cost on APBO 3,614 5,332 1,340 790 1,708 952 Expected return on assets (7,982 ) — (2,398 ) (2,474 ) (4,552 ) (1,394 ) Amortization of prior service credit (2,476 ) (3,674 ) (878 ) (342 ) (1,122 ) (726 ) Amortization of net (gain) loss 288 (348 ) 362 116 242 178 Net other postretirement benefit cost (income) ($5,374 ) $3,630 ($1,050 ) ($1,726 ) ($3,252 ) ($504 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,586 $3,112 $642 $258 $660 $612 Interest cost on APBO 3,994 5,578 1,366 834 1,878 1,000 Expected return on assets (8,684 ) — (2,606 ) (2,626 ) (4,892 ) (1,566 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of net loss 578 776 754 68 412 466 Net other postretirement benefit cost (income) ($5,082 ) $5,598 ($756 ) ($1,838 ) ($3,100 ) ($244 )
Entergy New Orleans [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $71 $41 $113 $6 $122 2018 $122 $46 $77 $21 $270 Reflected in Entergy Mississippi’s non-qualified pension costs in the second quarter of 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 in the second quarter of 2018 were settlement charges of $10 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs in the second quarter of 2018 were settlement charges of $139 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 six months ended June 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $144 $84 $188 $11 $246 2018 $254 $96 $157 $42 $407 Reflected in Entergy Mississippi’s non-qualified pension costs for the six months ended June 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 six months ended June 30, 2018 were settlement charges of $22 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the six months ended June 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 second 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 $5,261 $7,284 $1,629 $569 $1,350 $1,550 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,874 3,612 3,363 Expected return on assets (20,176 ) (22,652 ) (5,968 ) (2,697 ) (5,862 ) (4,677 ) Amortization of net loss 11,841 11,643 3,105 1,530 2,334 2,850 Net pension cost $11,101 $12,157 $2,834 $1,276 $1,434 $3,086 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 six months ended June 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 $10,522 $14,568 $3,258 $1,138 $2,700 $3,100 Interest cost on projected benefit obligation 28,350 31,764 8,136 3,748 7,224 6,727 Expected return on assets (40,352 ) (45,304 ) (11,936 ) (5,393 ) (11,724 ) (9,354 ) Amortization of net loss 23,682 23,286 6,209 3,059 4,668 5,700 Net pension cost $22,202 $24,314 $5,667 $2,552 $2,868 $6,173 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $12,378 $16,892 $3,644 $1,346 $3,178 $3,552 Interest cost on projected benefit obligation 26,008 29,880 7,538 3,626 6,696 6,454 Expected return on assets (43,702 ) (49,618 ) (13,004 ) (5,986 ) (13,046 ) (9,982 ) Amortization of net loss 26,824 28,900 7,220 3,908 5,252 7,430 Net pension cost $21,508 $26,054 $5,398 $2,894 $2,080 $7,454
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 June 2019 $9,338 $10,093 $2,671 $674 $739 $2,944 Remaining estimated pension contributions to be made in 2019 $17,774 $16,358 $5,030 $1,126 $906 $5,341
Entergy Texas [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for second 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, including amounts capitalized, for their employees for the six months ended June 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 $1,182 $2,320 $524 $184 $472 $486 Interest cost on APBO 3,614 5,332 1,340 790 1,708 952 Expected return on assets (7,982 ) — (2,398 ) (2,474 ) (4,552 ) (1,394 ) Amortization of prior service credit (2,476 ) (3,674 ) (878 ) (342 ) (1,122 ) (726 ) Amortization of net (gain) loss 288 (348 ) 362 116 242 178 Net other postretirement benefit cost (income) ($5,374 ) $3,630 ($1,050 ) ($1,726 ) ($3,252 ) ($504 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,586 $3,112 $642 $258 $660 $612 Interest cost on APBO 3,994 5,578 1,366 834 1,878 1,000 Expected return on assets (8,684 ) — (2,606 ) (2,626 ) (4,892 ) (1,566 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of net loss 578 776 754 68 412 466 Net other postretirement benefit cost (income) ($5,082 ) $5,598 ($756 ) ($1,838 ) ($3,100 ) ($244 )
Entergy Texas [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $71 $41 $113 $6 $122 2018 $122 $46 $77 $21 $270 Reflected in Entergy Mississippi’s non-qualified pension costs in the second quarter of 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 in the second quarter of 2018 were settlement charges of $10 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs in the second quarter of 2018 were settlement charges of $139 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 six months ended June 30, 2019 and 2018: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2019 $144 $84 $188 $11 $246 2018 $254 $96 $157 $42 $407 Reflected in Entergy Mississippi’s non-qualified pension costs for the six months ended June 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 six months ended June 30, 2018 were settlement charges of $22 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the six months ended June 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 second 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 $5,261 $7,284 $1,629 $569 $1,350 $1,550 Interest cost on projected benefit obligation 14,175 15,882 4,068 1,874 3,612 3,363 Expected return on assets (20,176 ) (22,652 ) (5,968 ) (2,697 ) (5,862 ) (4,677 ) Amortization of net loss 11,841 11,643 3,105 1,530 2,334 2,850 Net pension cost $11,101 $12,157 $2,834 $1,276 $1,434 $3,086 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 six months ended June 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 $10,522 $14,568 $3,258 $1,138 $2,700 $3,100 Interest cost on projected benefit obligation 28,350 31,764 8,136 3,748 7,224 6,727 Expected return on assets (40,352 ) (45,304 ) (11,936 ) (5,393 ) (11,724 ) (9,354 ) Amortization of net loss 23,682 23,286 6,209 3,059 4,668 5,700 Net pension cost $22,202 $24,314 $5,667 $2,552 $2,868 $6,173 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $12,378 $16,892 $3,644 $1,346 $3,178 $3,552 Interest cost on projected benefit obligation 26,008 29,880 7,538 3,626 6,696 6,454 Expected return on assets (43,702 ) (49,618 ) (13,004 ) (5,986 ) (13,046 ) (9,982 ) Amortization of net loss 26,824 28,900 7,220 3,908 5,252 7,430 Net pension cost $21,508 $26,054 $5,398 $2,894 $2,080 $7,454
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 June 2019 $9,338 $10,093 $2,671 $674 $739 $2,944 Remaining estimated pension contributions to be made in 2019 $17,774 $16,358 $5,030 $1,126 $906 $5,341
System Energy [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for second 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, including amounts capitalized, for their employees for the six months ended June 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 $1,182 $2,320 $524 $184 $472 $486 Interest cost on APBO 3,614 5,332 1,340 790 1,708 952 Expected return on assets (7,982 ) — (2,398 ) (2,474 ) (4,552 ) (1,394 ) Amortization of prior service credit (2,476 ) (3,674 ) (878 ) (342 ) (1,122 ) (726 ) Amortization of net (gain) loss 288 (348 ) 362 116 242 178 Net other postretirement benefit cost (income) ($5,374 ) $3,630 ($1,050 ) ($1,726 ) ($3,252 ) ($504 ) 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,586 $3,112 $642 $258 $660 $612 Interest cost on APBO 3,994 5,578 1,366 834 1,878 1,000 Expected return on assets (8,684 ) — (2,606 ) (2,626 ) (4,892 ) (1,566 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of net loss 578 776 754 68 412 466 Net other postretirement benefit cost (income) ($5,082 ) $5,598 ($756 ) ($1,838 ) ($3,100 ) ($244 )

Business Segment Information (T

Business Segment Information (Tables) - Entergy Corporation [Member]	6 Months Ended
	Jun. 30, 2019
Segment Financial Information	Entergy’s segment financial information for the second quarters of 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $2,376,437 $289,783 $2 ($13 ) $2,666,209 Income taxes $21,150 ($9,290 ) ($10,402 ) $— $1,458 Consolidated net income (loss) $334,752 ($25,382 ) ($36,939 ) ($31,898 ) $240,533 2018 Operating revenues $2,360,208 $308,602 $— ($40 ) $2,668,770 Income taxes ($240,324 ) ($30,144 ) ($10,128 ) $— ($280,596 ) Consolidated net income (loss) $378,394 ($56,337 ) ($41,299 ) ($31,898 ) $248,860 Entergy’s segment financial information for the six months ended June 30, 2019 and 2018 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2019 Operating revenues $4,552,419 $723,394 $2 ($23) $5,275,792 Income taxes $9,586 $56,618 ($21,975) $— $44,229 Consolidated net income (loss) $568,900 $71,697 ($77,620) ($63,797) $499,180 Total assets as of June 30, 2019 $47,297,832 $5,211,771 $493,962 ($2,437,820) $50,565,745 2018 Operating revenues $4,665,197 $727,526 $— ($73) $5,392,650 Income taxes ($188,100) ($31,222) ($17,611) $— ($236,933) Consolidated net income (loss) $596,333 ($74,116) ($73,361) ($63,797) $385,059 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 second 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 April 1, $213 $14 $227 $109 $14 $123 Restructuring costs accrued 22 — 22 34 — 34 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $16 million in the second quarter 2019 and $69 million in the second quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 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 56 — 56 60 — 60 Cash paid out 54 — 54 — — — Balance as of June 30, $181 $14 $195 $143 $14 $157 In addition, Entergy Wholesale Commodities incurred $90 million in the six months ended June 30, 2019 and $142 million in the six months ended June 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)	6 Months Ended
	Jun. 30, 2019
Fair Values Of Derivative Instruments	The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of June 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) $51 ($2) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $21 ($2) $19 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $3 ($3) $— 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) $8 ($3) $5 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) $1 $— $1 Utility Financial transmission rights Prepayments and other $31 ($2) $29 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $3 ($3) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($1) $1 Entergy Wholesale Commodities Natural gas swaps and options Other current liabilities $5 $— $5 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 June 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $51 million held and $2 million posted as of June 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 June 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 $126 Competitive businesses operating revenues $6 2018 Electricity swaps and options ($80) Competitive businesses operating revenues $3 (a) Before taxes of $1 million and $1 million for the three months ended June 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 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 $152 Competitive businesses operating revenues $57 2018 Electricity swaps and options $11 Competitive businesses operating revenues ($27) (a) Before taxes of $12 million and ($6) million for the six months ended June 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 June 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) ($6) Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $41 Electricity swaps and options $— (c) Competitive business operating revenues $1 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 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) ($7) Financial transmission rights $— Purchased power expense (b) $53 Electricity swaps and options $— (c) Competitive business operating revenues $3 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $6 Financial transmission rights $— Purchased power expense (b) $73 Electricity swaps and options $— (c) Competitive business operating revenues $1 (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 June 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 $575 $— $— $575 Decommissioning trust funds (a): Equity securities 1,293 — — 1,293 Debt securities 1,630 1,783 — 3,413 Common trusts (b) 2,363 Power contracts — — 73 73 Securitization recovery trust account 39 — — 39 Escrow accounts 408 — — 408 Gas hedge contracts — 1 — 1 Financial transmission rights — — 29 29 $3,945 $1,784 $102 $8,194 Liabilities: Power contracts $— $— $1 $1 Gas hedge contracts 5 1 — 6 $5 $1 $1 $7 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 June 30, 2019 and 2018 : 2019 2018 Power Contracts Financial transmission rights Power Contracts Financial transmission rights (In Millions) Balance as of April 1, ($46 ) $5 $75 $8 Total gains (losses) for the period (a) Included in earnings (2 ) — (15 ) — Included in other comprehensive income 126 — (80 ) — Included as a regulatory liability/asset — 21 — 28 Issuances of financial transmission rights — 35 — 46 Settlements (6 ) (32 ) (5 ) (41 ) Balance as of June 30, $72 $29 ($25 ) $41 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is $1.4 million for the three months ended June 30, 2019 and ($0.8) million for the three months ended June 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 six months ended June 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 3 — (1 ) (1 ) Included in other comprehensive income 152 — 11 — Included as a regulatory liability/asset — 32 — 48 Issuances of financial transmission rights — 35 — 46 Settlements (52 ) (53 ) 30 (73 ) Balance as of June 30, $72 $29 ($25 ) $41 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($3.5) million for the six months ended June 30, 2019 and ($0.7) million for the six months ended June 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 June 30, 2019 : Transaction Type Fair Value as of June 30, 2019 Significant Unobservable Inputs Range from Average % Effect on Fair Value (In Millions) (In Millions) Power contracts - electricity swaps $72 Unit contingent discount +/- 4% - 4.75% $6 - $7
Entergy Arkansas [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 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) $1.4 $— $1.4 Entergy Louisiana Financial transmission rights Prepayments and other $8.3 ($0.1) $8.2 Entergy Arkansas Financial transmission rights Prepayments and other $15.9 ($0.3) $15.6 Entergy Louisiana Financial transmission rights Prepayments and other $2.8 $— $2.8 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 ($0.1) $2.0 Entergy New Orleans Financial transmission rights Prepayments and other $2.1 ($1.5) $0.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $1.9 $— $1.9 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $0.7 $— $0.7 Entergy Louisiana Natural gas swaps Other current liabilities $3.1 $— $3.1 Entergy Mississippi 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 June 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 ($2.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $3.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense $2.2 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.8 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $2.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $25.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $9.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($1.8) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($1.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.2) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.2 (a) Entergy New Orleans Financial transmission rights Purchased power expense $12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $26.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $8.1 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.7 (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 $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $43.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $17.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $8.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.3) (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 $29.1 $— $— $29.1 Decommissioning trust funds (a): Equity securities 5.1 — — 5.1 Debt securities 107.5 294.1 — 401.6 Common trusts (b) 625.1 Securitization recovery trust account 3.8 — — 3.8 Financial transmission rights — — 8.2 8.2 $145.5 $294.1 $8.2 $1,072.9 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 June 30, 2019 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.1 $2.8 $0.7 $0.5 ($0.3 ) Issuances of financial transmission rights 9.6 18.7 3.9 2.7 0.1 Gains included as a regulatory liability/asset 1.1 11.8 0.4 (0.5 ) 8.6 Settlements (3.6 ) (17.7 ) (2.2 ) (0.7 ) (7.8 ) Balance as of June 30, $8.2 $15.6 $2.8 $2.0 $0.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2018 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.8 $3.4 $0.9 $0.7 $1.4 Issuances of financial transmission rights 11.8 20.0 4.5 3.7 6.1 Gains included as a regulatory liability/asset (1.0 ) 20.6 8.8 3.8 (4.6 ) Settlements (2.1 ) (25.8 ) (9.8 ) (5.2 ) 1.8 Balance as of June 30, $10.5 $18.2 $4.4 $3.0 $4.7 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 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 7.2 15.1 — 0.6 9.1 Settlements (12.0 ) (26.5 ) (3.3 ) (2.6 ) (8.1 ) Balance as of June 30, $8.2 $15.6 $2.8 $2.0 $0.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 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 5.8 31.4 15.4 5.5 (10.1 ) Settlements (10.1 ) (43.4 ) (17.6 ) (8.4 ) 5.3 Balance as of June 30, $10.5 $18.2 $4.4 $3.0 $4.7
Entergy Louisiana [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 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) $1.4 $— $1.4 Entergy Louisiana Financial transmission rights Prepayments and other $8.3 ($0.1) $8.2 Entergy Arkansas Financial transmission rights Prepayments and other $15.9 ($0.3) $15.6 Entergy Louisiana Financial transmission rights Prepayments and other $2.8 $— $2.8 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 ($0.1) $2.0 Entergy New Orleans Financial transmission rights Prepayments and other $2.1 ($1.5) $0.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $1.9 $— $1.9 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $0.7 $— $0.7 Entergy Louisiana Natural gas swaps Other current liabilities $3.1 $— $3.1 Entergy Mississippi 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 June 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 ($2.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $3.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense $2.2 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.8 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $2.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $25.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $9.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($1.8) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($1.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.2) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.2 (a) Entergy New Orleans Financial transmission rights Purchased power expense $12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $26.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $8.1 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.7 (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 $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $43.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $17.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $8.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.3) (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 $44.5 $— $— $44.5 Decommissioning trust funds (a): Equity securities 8.6 — — 8.6 Debt securities 191.3 385.0 — 576.3 Common trusts (b) 876.2 Escrow accounts 292.9 — — 292.9 Securitization recovery trust account 3.2 — — 3.2 Gas hedge contracts 0.1 1.4 — 1.5 Financial transmission rights — — 15.6 15.6 $540.6 $386.4 $15.6 $1,818.8 Liabilities: Gas hedge contracts $1.9 $0.7 $— $2.6 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 June 30, 2019 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.1 $2.8 $0.7 $0.5 ($0.3 ) Issuances of financial transmission rights 9.6 18.7 3.9 2.7 0.1 Gains included as a regulatory liability/asset 1.1 11.8 0.4 (0.5 ) 8.6 Settlements (3.6 ) (17.7 ) (2.2 ) (0.7 ) (7.8 ) Balance as of June 30, $8.2 $15.6 $2.8 $2.0 $0.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2018 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.8 $3.4 $0.9 $0.7 $1.4 Issuances of financial transmission rights 11.8 20.0 4.5 3.7 6.1 Gains included as a regulatory liability/asset (1.0 ) 20.6 8.8 3.8 (4.6 ) Settlements (2.1 ) (25.8 ) (9.8 ) (5.2 ) 1.8 Balance as of June 30, $10.5 $18.2 $4.4 $3.0 $4.7 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 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 7.2 15.1 — 0.6 9.1 Settlements (12.0 ) (26.5 ) (3.3 ) (2.6 ) (8.1 ) Balance as of June 30, $8.2 $15.6 $2.8 $2.0 $0.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 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 5.8 31.4 15.4 5.5 (10.1 ) Settlements (10.1 ) (43.4 ) (17.6 ) (8.4 ) 5.3 Balance as of June 30, $10.5 $18.2 $4.4 $3.0 $4.7
Entergy Mississippi [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 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) $1.4 $— $1.4 Entergy Louisiana Financial transmission rights Prepayments and other $8.3 ($0.1) $8.2 Entergy Arkansas Financial transmission rights Prepayments and other $15.9 ($0.3) $15.6 Entergy Louisiana Financial transmission rights Prepayments and other $2.8 $— $2.8 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 ($0.1) $2.0 Entergy New Orleans Financial transmission rights Prepayments and other $2.1 ($1.5) $0.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $1.9 $— $1.9 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $0.7 $— $0.7 Entergy Louisiana Natural gas swaps Other current liabilities $3.1 $— $3.1 Entergy Mississippi 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 June 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 ($2.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $3.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense $2.2 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.8 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $2.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $25.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $9.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($1.8) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($1.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.2) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.2 (a) Entergy New Orleans Financial transmission rights Purchased power expense $12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $26.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $8.1 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.7 (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 $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $43.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $17.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $8.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.3) (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 $123.7 $— $— $123.7 Escrow accounts 32.8 — — 32.8 Financial transmission rights — — 2.8 2.8 $156.5 $— $2.8 $159.3 Liabilities: Gas hedge contracts $3.1 $— $— $3.1 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 June 30, 2019 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.1 $2.8 $0.7 $0.5 ($0.3 ) Issuances of financial transmission rights 9.6 18.7 3.9 2.7 0.1 Gains included as a regulatory liability/asset 1.1 11.8 0.4 (0.5 ) 8.6 Settlements (3.6 ) (17.7 ) (2.2 ) (0.7 ) (7.8 ) Balance as of June 30, $8.2 $15.6 $2.8 $2.0 $0.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2018 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.8 $3.4 $0.9 $0.7 $1.4 Issuances of financial transmission rights 11.8 20.0 4.5 3.7 6.1 Gains included as a regulatory liability/asset (1.0 ) 20.6 8.8 3.8 (4.6 ) Settlements (2.1 ) (25.8 ) (9.8 ) (5.2 ) 1.8 Balance as of June 30, $10.5 $18.2 $4.4 $3.0 $4.7 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 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 7.2 15.1 — 0.6 9.1 Settlements (12.0 ) (26.5 ) (3.3 ) (2.6 ) (8.1 ) Balance as of June 30, $8.2 $15.6 $2.8 $2.0 $0.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 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 5.8 31.4 15.4 5.5 (10.1 ) Settlements (10.1 ) (43.4 ) (17.6 ) (8.4 ) 5.3 Balance as of June 30, $10.5 $18.2 $4.4 $3.0 $4.7
Entergy New Orleans [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 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) $1.4 $— $1.4 Entergy Louisiana Financial transmission rights Prepayments and other $8.3 ($0.1) $8.2 Entergy Arkansas Financial transmission rights Prepayments and other $15.9 ($0.3) $15.6 Entergy Louisiana Financial transmission rights Prepayments and other $2.8 $— $2.8 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 ($0.1) $2.0 Entergy New Orleans Financial transmission rights Prepayments and other $2.1 ($1.5) $0.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $1.9 $— $1.9 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $0.7 $— $0.7 Entergy Louisiana Natural gas swaps Other current liabilities $3.1 $— $3.1 Entergy Mississippi 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 June 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 ($2.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $3.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense $2.2 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.8 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $2.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $25.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $9.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($1.8) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($1.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.2) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.2 (a) Entergy New Orleans Financial transmission rights Purchased power expense $12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $26.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $8.1 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.7 (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 $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $43.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $17.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $8.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.3) (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 $1.5 $— $— $1.5 Escrow accounts 81.8 — — 81.8 Financial transmission rights — — 2.0 2.0 $83.3 $— $2.0 $85.3 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 June 30, 2019 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.1 $2.8 $0.7 $0.5 ($0.3 ) Issuances of financial transmission rights 9.6 18.7 3.9 2.7 0.1 Gains included as a regulatory liability/asset 1.1 11.8 0.4 (0.5 ) 8.6 Settlements (3.6 ) (17.7 ) (2.2 ) (0.7 ) (7.8 ) Balance as of June 30, $8.2 $15.6 $2.8 $2.0 $0.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2018 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.8 $3.4 $0.9 $0.7 $1.4 Issuances of financial transmission rights 11.8 20.0 4.5 3.7 6.1 Gains included as a regulatory liability/asset (1.0 ) 20.6 8.8 3.8 (4.6 ) Settlements (2.1 ) (25.8 ) (9.8 ) (5.2 ) 1.8 Balance as of June 30, $10.5 $18.2 $4.4 $3.0 $4.7 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 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 7.2 15.1 — 0.6 9.1 Settlements (12.0 ) (26.5 ) (3.3 ) (2.6 ) (8.1 ) Balance as of June 30, $8.2 $15.6 $2.8 $2.0 $0.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 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 5.8 31.4 15.4 5.5 (10.1 ) Settlements (10.1 ) (43.4 ) (17.6 ) (8.4 ) 5.3 Balance as of June 30, $10.5 $18.2 $4.4 $3.0 $4.7
Entergy Texas [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 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) $1.4 $— $1.4 Entergy Louisiana Financial transmission rights Prepayments and other $8.3 ($0.1) $8.2 Entergy Arkansas Financial transmission rights Prepayments and other $15.9 ($0.3) $15.6 Entergy Louisiana Financial transmission rights Prepayments and other $2.8 $— $2.8 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 ($0.1) $2.0 Entergy New Orleans Financial transmission rights Prepayments and other $2.1 ($1.5) $0.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $1.9 $— $1.9 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $0.7 $— $0.7 Entergy Louisiana Natural gas swaps Other current liabilities $3.1 $— $3.1 Entergy Mississippi 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 June 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $10.2 thousand for Entergy New Orleans, and $2.2 million for Entergy Texas. 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 June 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 ($2.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $3.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense $2.2 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.8 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $2.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $25.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $9.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($1.8) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($1.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.2) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.2 (a) Entergy New Orleans Financial transmission rights Purchased power expense $12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $26.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $8.1 (b) Entergy Texas 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.7 (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 $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $43.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $17.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $8.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.3) (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 : Securitization recovery trust account $30.2 $— $— $30.2 Financial transmission rights — — 0.6 0.6 $30.2 $— $0.6 $30.8 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 June 30, 2019 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.1 $2.8 $0.7 $0.5 ($0.3 ) Issuances of financial transmission rights 9.6 18.7 3.9 2.7 0.1 Gains included as a regulatory liability/asset 1.1 11.8 0.4 (0.5 ) 8.6 Settlements (3.6 ) (17.7 ) (2.2 ) (0.7 ) (7.8 ) Balance as of June 30, $8.2 $15.6 $2.8 $2.0 $0.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2018 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.8 $3.4 $0.9 $0.7 $1.4 Issuances of financial transmission rights 11.8 20.0 4.5 3.7 6.1 Gains included as a regulatory liability/asset (1.0 ) 20.6 8.8 3.8 (4.6 ) Settlements (2.1 ) (25.8 ) (9.8 ) (5.2 ) 1.8 Balance as of June 30, $10.5 $18.2 $4.4 $3.0 $4.7 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 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 7.2 15.1 — 0.6 9.1 Settlements (12.0 ) (26.5 ) (3.3 ) (2.6 ) (8.1 ) Balance as of June 30, $8.2 $15.6 $2.8 $2.0 $0.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 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 5.8 31.4 15.4 5.5 (10.1 ) Settlements (10.1 ) (43.4 ) (17.6 ) (8.4 ) 5.3 Balance as of June 30, $10.5 $18.2 $4.4 $3.0 $4.7
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 $82.9 $— $— $82.9 Decommissioning trust funds (a): Equity securities 5.2 — — 5.2 Debt securities 229.9 156.7 — 386.6 Common trusts (b) 595.0 $318.0 $156.7 $— $1,069.7 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)	6 Months Ended
	Jun. 30, 2019
Securities Held	The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities (a) $2,914 $92 $2 2018 Debt Securities (a) $2,495 $19 $35 (a) Debt securities presented herein do not include the $499 million and $389 million of debt securities held in the wholly-owned registered investment company as of June 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $163 $— More than 12 months 180 2 Total $343 $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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $226 $199 1 year - 5 years 1,342 1,066 5 years - 10 years 654 544 10 years - 15 years 64 77 15 years - 20 years 91 78 20 years+ 537 531 Total $2,914 $2,495
Entergy Arkansas [Member]
Securities Held	The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $401.6 $8.8 $0.5 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $0.5 $— More than 12 months 52.7 0.5 Total $53.2 $0.5 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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $59.5 $32.5 1 year - 5 years 143.2 170.3 5 years - 10 years 129.0 114.0 10 years - 15 years 11.1 10.3 15 years - 20 years 9.7 8.1 20 years+ 49.1 46.1 Total $401.6 $381.3
Entergy Louisiana [Member]
Securities Held	The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $576.3 $26.6 $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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $5.0 $— More than 12 months 31.7 0.3 Total $36.7 $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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $52.5 $31.1 1 year - 5 years 128.7 130.5 5 years - 10 years 134.4 111.0 10 years - 15 years 27.6 29.0 15 years - 20 years 44.3 37.1 20 years+ 188.8 194.2 Total $576.3 $532.9
System Energy [Member]
Securities Held	The available-for-sale securities held as of June 30, 2019 and December 31, 2018 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2019 Debt Securities $386.6 $14.1 $0.2 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 June 30, 2019 : Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $42.6 $0.1 More than 12 months 14.1 0.1 Total $56.7 $0.2 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 $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 June 30, 2019 and December 31, 2018 are as follows: 2019 2018 (In Millions) Less than 1 year $11.3 $22.8 1 year - 5 years 197.6 188.0 5 years - 10 years 90.5 73.4 10 years - 15 years 1.7 5.2 15 years - 20 years 3.2 10.2 20 years+ 82.3 64.6 Total $386.6 $364.2

Income Taxes Income Taxes (Tabl

Income Taxes Income Taxes (Tables)	6 Months Ended
	Jun. 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 the Registrant Subsidiaries’ regulatory liability for income taxes for the three months ended June 30, 2019 and 2018 and the six months ended June 30, 2019 and 2018, as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In Millions) Entergy Arkansas $25 $108 $57 $108 Entergy Louisiana 7 31 14 31 Entergy Mississippi — 129 — 129 Entergy New Orleans 2 — 2 — Entergy Texas 20 — 42 — System Entergy 7 11 7 11
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 the Registrant Subsidiaries’ regulatory liability for income taxes for the three months ended June 30, 2019 and 2018 and the six months ended June 30, 2019 and 2018, as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In Millions) Entergy Arkansas $25 $108 $57 $108 Entergy Louisiana 7 31 14 31 Entergy Mississippi — 129 — 129 Entergy New Orleans 2 — 2 — Entergy Texas 20 — 42 — System Entergy 7 11 7 11
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 the Registrant Subsidiaries’ regulatory liability for income taxes for the three months ended June 30, 2019 and 2018 and the six months ended June 30, 2019 and 2018, as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In Millions) Entergy Arkansas $25 $108 $57 $108 Entergy Louisiana 7 31 14 31 Entergy Mississippi — 129 — 129 Entergy New Orleans 2 — 2 — Entergy Texas 20 — 42 — System Entergy 7 11 7 11
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 the Registrant Subsidiaries’ regulatory liability for income taxes for the three months ended June 30, 2019 and 2018 and the six months ended June 30, 2019 and 2018, as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In Millions) Entergy Arkansas $25 $108 $57 $108 Entergy Louisiana 7 31 14 31 Entergy Mississippi — 129 — 129 Entergy New Orleans 2 — 2 — Entergy Texas 20 — 42 — System Entergy 7 11 7 11
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 the Registrant Subsidiaries’ regulatory liability for income taxes for the three months ended June 30, 2019 and 2018 and the six months ended June 30, 2019 and 2018, as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In Millions) Entergy Arkansas $25 $108 $57 $108 Entergy Louisiana 7 31 14 31 Entergy Mississippi — 129 — 129 Entergy New Orleans 2 — 2 — Entergy Texas 20 — 42 — System Entergy 7 11 7 11
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 the Registrant Subsidiaries’ regulatory liability for income taxes for the three months ended June 30, 2019 and 2018 and the six months ended June 30, 2019 and 2018, as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In Millions) Entergy Arkansas $25 $108 $57 $108 Entergy Louisiana 7 31 14 31 Entergy Mississippi — 129 — 129 Entergy New Orleans 2 — 2 — Entergy Texas 20 — 42 — System Entergy 7 11 7 11
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 the Registrant Subsidiaries’ regulatory liability for income taxes for the three months ended June 30, 2019 and 2018 and the six months ended June 30, 2019 and 2018, as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In Millions) Entergy Arkansas $25 $108 $57 $108 Entergy Louisiana 7 31 14 31 Entergy Mississippi — 129 — 129 Entergy New Orleans 2 — 2 — Entergy Texas 20 — 42 — System Entergy 7 11 7 11

Revenue Recognition Revenue Rec

Revenue Recognition Revenue Recognition (Tables)	6 Months Ended
	Jun. 30, 2019
Disaggregation of Revenue [Table Text Block]	Entergy’s total revenues for the three months ended June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $770,373 $768,710 Commercial 595,025 581,899 Industrial 641,733 624,818 Governmental 57,623 56,823 Total billed retail 2,064,754 2,032,250 Sales for resale (a) 75,318 69,212 Other electric revenues (b) 195,952 219,391 Non-customer revenues (c) 9,703 9,372 Total electric revenues 2,345,727 2,330,225 Natural gas 30,699 29,943 Entergy Wholesale Commodities: Competitive businesses sales (a) 280,398 331,562 Non-customer revenues (c) 9,385 (22,960 ) Total competitive businesses 289,783 308,602 Total operating revenues $2,666,209 $2,668,770 Entergy’s total revenues for the six months ended June 30, 2019 and 2018 are as follows: 2019 2018 (In Thousands) Utility: Residential $1,572,911 $1,660,795 Commercial 1,149,082 1,177,620 Industrial 1,242,734 1,222,004 Governmental 110,584 113,301 Total billed retail 4,075,311 4,173,720 Sales for resale (a) 159,753 138,738 Other electric revenues (b) 211,422 246,822 Non-customer revenues (c) 20,265 19,206 Total electric revenues 4,466,751 4,578,486 Natural gas 85,647 86,638 Entergy Wholesale Commodities: Competitive businesses sales (a) 640,869 740,697 Non-customer revenues (c) 82,525 (13,171 ) Total competitive businesses 723,394 727,526 Total operating revenues $5,275,792 $5,392,650
Entergy Arkansas [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $157,714 $290,366 $116,801 $58,621 $146,871 Commercial 125,555 232,134 102,275 53,981 81,080 Industrial 118,913 384,919 38,739 8,490 90,672 Governmental 4,971 17,925 10,521 18,984 5,222 Total billed retail 407,153 925,344 268,336 140,076 323,845 Sales for resale (a) 74,501 83,208 4,994 8,579 14,772 Other electric revenues (b) 58,209 80,307 26,982 7,263 24,656 Non-customer revenues (c) 3,066 5,400 2,425 1,234 307 Total electric revenues 542,929 1,094,259 302,737 157,152 363,580 Natural gas — 12,058 — 18,641 — Total operating revenues $542,929 $1,106,317 $302,737 $175,793 $363,580 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $159,130 $267,915 $132,730 $58,232 $150,703 Commercial 93,741 221,740 117,351 54,524 94,544 Industrial 97,973 368,678 46,129 9,267 102,771 Governmental 3,766 16,705 11,452 18,448 6,452 Total billed retail 354,610 875,038 307,662 140,471 354,470 Sales for resale (a) 53,195 111,801 11,776 6,190 25,177 Other electric revenues (b) 84,102 70,027 31,696 11,623 23,468 Non-customer revenues (c) 2,698 4,823 2,555 1,318 371 Total electric revenues 494,605 1,061,689 353,689 159,602 403,486 Natural gas — 11,099 — 18,844 — Total operating revenues $494,605 $1,072,788 $353,689 $178,446 $403,486 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $367,581 $554,431 $245,610 $110,697 $294,592 Commercial 250,133 438,912 200,189 99,723 160,125 Industrial 240,491 731,598 76,436 15,740 178,470 Governmental 9,869 34,817 20,557 34,886 10,455 Total billed retail 868,074 1,759,758 542,792 261,046 643,642 Sales for resale (a) 154,085 167,164 9,808 18,803 31,548 Other electric revenues (b) 60,514 92,746 27,387 5,556 28,153 Non-customer revenues (c) 6,068 11,284 4,994 2,630 711 Total electric revenues 1,088,741 2,030,952 584,981 288,035 704,054 Natural gas — 34,695 — 50,952 — Total operating revenues $1,088,741 $2,065,647 $584,981 $338,987 $704,054 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $394,654 $563,433 $281,073 $122,807 $298,828 Commercial 214,375 446,667 227,811 108,796 179,971 Industrial 209,450 721,014 88,629 16,838 186,073 Governmental 8,414 34,015 22,300 36,139 12,433 Total billed retail 826,893 1,765,129 619,813 284,580 677,305 Sales for resale (a) 119,299 201,056 13,769 19,527 48,538 Other electric revenues (b) 94,125 90,529 30,977 8,511 25,733 Non-customer revenues (c) 5,312 10,081 4,873 2,802 850 Total electric revenues 1,045,629 2,066,795 669,432 315,420 752,426 Natural gas — 35,337 — 51,301 — Total operating revenues $1,045,629 $2,102,132 $669,432 $366,721 $752,426 (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 June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $157,714 $290,366 $116,801 $58,621 $146,871 Commercial 125,555 232,134 102,275 53,981 81,080 Industrial 118,913 384,919 38,739 8,490 90,672 Governmental 4,971 17,925 10,521 18,984 5,222 Total billed retail 407,153 925,344 268,336 140,076 323,845 Sales for resale (a) 74,501 83,208 4,994 8,579 14,772 Other electric revenues (b) 58,209 80,307 26,982 7,263 24,656 Non-customer revenues (c) 3,066 5,400 2,425 1,234 307 Total electric revenues 542,929 1,094,259 302,737 157,152 363,580 Natural gas — 12,058 — 18,641 — Total operating revenues $542,929 $1,106,317 $302,737 $175,793 $363,580 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $159,130 $267,915 $132,730 $58,232 $150,703 Commercial 93,741 221,740 117,351 54,524 94,544 Industrial 97,973 368,678 46,129 9,267 102,771 Governmental 3,766 16,705 11,452 18,448 6,452 Total billed retail 354,610 875,038 307,662 140,471 354,470 Sales for resale (a) 53,195 111,801 11,776 6,190 25,177 Other electric revenues (b) 84,102 70,027 31,696 11,623 23,468 Non-customer revenues (c) 2,698 4,823 2,555 1,318 371 Total electric revenues 494,605 1,061,689 353,689 159,602 403,486 Natural gas — 11,099 — 18,844 — Total operating revenues $494,605 $1,072,788 $353,689 $178,446 $403,486 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $367,581 $554,431 $245,610 $110,697 $294,592 Commercial 250,133 438,912 200,189 99,723 160,125 Industrial 240,491 731,598 76,436 15,740 178,470 Governmental 9,869 34,817 20,557 34,886 10,455 Total billed retail 868,074 1,759,758 542,792 261,046 643,642 Sales for resale (a) 154,085 167,164 9,808 18,803 31,548 Other electric revenues (b) 60,514 92,746 27,387 5,556 28,153 Non-customer revenues (c) 6,068 11,284 4,994 2,630 711 Total electric revenues 1,088,741 2,030,952 584,981 288,035 704,054 Natural gas — 34,695 — 50,952 — Total operating revenues $1,088,741 $2,065,647 $584,981 $338,987 $704,054 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $394,654 $563,433 $281,073 $122,807 $298,828 Commercial 214,375 446,667 227,811 108,796 179,971 Industrial 209,450 721,014 88,629 16,838 186,073 Governmental 8,414 34,015 22,300 36,139 12,433 Total billed retail 826,893 1,765,129 619,813 284,580 677,305 Sales for resale (a) 119,299 201,056 13,769 19,527 48,538 Other electric revenues (b) 94,125 90,529 30,977 8,511 25,733 Non-customer revenues (c) 5,312 10,081 4,873 2,802 850 Total electric revenues 1,045,629 2,066,795 669,432 315,420 752,426 Natural gas — 35,337 — 51,301 — Total operating revenues $1,045,629 $2,102,132 $669,432 $366,721 $752,426 (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 June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $157,714 $290,366 $116,801 $58,621 $146,871 Commercial 125,555 232,134 102,275 53,981 81,080 Industrial 118,913 384,919 38,739 8,490 90,672 Governmental 4,971 17,925 10,521 18,984 5,222 Total billed retail 407,153 925,344 268,336 140,076 323,845 Sales for resale (a) 74,501 83,208 4,994 8,579 14,772 Other electric revenues (b) 58,209 80,307 26,982 7,263 24,656 Non-customer revenues (c) 3,066 5,400 2,425 1,234 307 Total electric revenues 542,929 1,094,259 302,737 157,152 363,580 Natural gas — 12,058 — 18,641 — Total operating revenues $542,929 $1,106,317 $302,737 $175,793 $363,580 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $159,130 $267,915 $132,730 $58,232 $150,703 Commercial 93,741 221,740 117,351 54,524 94,544 Industrial 97,973 368,678 46,129 9,267 102,771 Governmental 3,766 16,705 11,452 18,448 6,452 Total billed retail 354,610 875,038 307,662 140,471 354,470 Sales for resale (a) 53,195 111,801 11,776 6,190 25,177 Other electric revenues (b) 84,102 70,027 31,696 11,623 23,468 Non-customer revenues (c) 2,698 4,823 2,555 1,318 371 Total electric revenues 494,605 1,061,689 353,689 159,602 403,486 Natural gas — 11,099 — 18,844 — Total operating revenues $494,605 $1,072,788 $353,689 $178,446 $403,486 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $367,581 $554,431 $245,610 $110,697 $294,592 Commercial 250,133 438,912 200,189 99,723 160,125 Industrial 240,491 731,598 76,436 15,740 178,470 Governmental 9,869 34,817 20,557 34,886 10,455 Total billed retail 868,074 1,759,758 542,792 261,046 643,642 Sales for resale (a) 154,085 167,164 9,808 18,803 31,548 Other electric revenues (b) 60,514 92,746 27,387 5,556 28,153 Non-customer revenues (c) 6,068 11,284 4,994 2,630 711 Total electric revenues 1,088,741 2,030,952 584,981 288,035 704,054 Natural gas — 34,695 — 50,952 — Total operating revenues $1,088,741 $2,065,647 $584,981 $338,987 $704,054 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $394,654 $563,433 $281,073 $122,807 $298,828 Commercial 214,375 446,667 227,811 108,796 179,971 Industrial 209,450 721,014 88,629 16,838 186,073 Governmental 8,414 34,015 22,300 36,139 12,433 Total billed retail 826,893 1,765,129 619,813 284,580 677,305 Sales for resale (a) 119,299 201,056 13,769 19,527 48,538 Other electric revenues (b) 94,125 90,529 30,977 8,511 25,733 Non-customer revenues (c) 5,312 10,081 4,873 2,802 850 Total electric revenues 1,045,629 2,066,795 669,432 315,420 752,426 Natural gas — 35,337 — 51,301 — Total operating revenues $1,045,629 $2,102,132 $669,432 $366,721 $752,426 (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 June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $157,714 $290,366 $116,801 $58,621 $146,871 Commercial 125,555 232,134 102,275 53,981 81,080 Industrial 118,913 384,919 38,739 8,490 90,672 Governmental 4,971 17,925 10,521 18,984 5,222 Total billed retail 407,153 925,344 268,336 140,076 323,845 Sales for resale (a) 74,501 83,208 4,994 8,579 14,772 Other electric revenues (b) 58,209 80,307 26,982 7,263 24,656 Non-customer revenues (c) 3,066 5,400 2,425 1,234 307 Total electric revenues 542,929 1,094,259 302,737 157,152 363,580 Natural gas — 12,058 — 18,641 — Total operating revenues $542,929 $1,106,317 $302,737 $175,793 $363,580 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $159,130 $267,915 $132,730 $58,232 $150,703 Commercial 93,741 221,740 117,351 54,524 94,544 Industrial 97,973 368,678 46,129 9,267 102,771 Governmental 3,766 16,705 11,452 18,448 6,452 Total billed retail 354,610 875,038 307,662 140,471 354,470 Sales for resale (a) 53,195 111,801 11,776 6,190 25,177 Other electric revenues (b) 84,102 70,027 31,696 11,623 23,468 Non-customer revenues (c) 2,698 4,823 2,555 1,318 371 Total electric revenues 494,605 1,061,689 353,689 159,602 403,486 Natural gas — 11,099 — 18,844 — Total operating revenues $494,605 $1,072,788 $353,689 $178,446 $403,486 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $367,581 $554,431 $245,610 $110,697 $294,592 Commercial 250,133 438,912 200,189 99,723 160,125 Industrial 240,491 731,598 76,436 15,740 178,470 Governmental 9,869 34,817 20,557 34,886 10,455 Total billed retail 868,074 1,759,758 542,792 261,046 643,642 Sales for resale (a) 154,085 167,164 9,808 18,803 31,548 Other electric revenues (b) 60,514 92,746 27,387 5,556 28,153 Non-customer revenues (c) 6,068 11,284 4,994 2,630 711 Total electric revenues 1,088,741 2,030,952 584,981 288,035 704,054 Natural gas — 34,695 — 50,952 — Total operating revenues $1,088,741 $2,065,647 $584,981 $338,987 $704,054 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $394,654 $563,433 $281,073 $122,807 $298,828 Commercial 214,375 446,667 227,811 108,796 179,971 Industrial 209,450 721,014 88,629 16,838 186,073 Governmental 8,414 34,015 22,300 36,139 12,433 Total billed retail 826,893 1,765,129 619,813 284,580 677,305 Sales for resale (a) 119,299 201,056 13,769 19,527 48,538 Other electric revenues (b) 94,125 90,529 30,977 8,511 25,733 Non-customer revenues (c) 5,312 10,081 4,873 2,802 850 Total electric revenues 1,045,629 2,066,795 669,432 315,420 752,426 Natural gas — 35,337 — 51,301 — Total operating revenues $1,045,629 $2,102,132 $669,432 $366,721 $752,426 (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 June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $157,714 $290,366 $116,801 $58,621 $146,871 Commercial 125,555 232,134 102,275 53,981 81,080 Industrial 118,913 384,919 38,739 8,490 90,672 Governmental 4,971 17,925 10,521 18,984 5,222 Total billed retail 407,153 925,344 268,336 140,076 323,845 Sales for resale (a) 74,501 83,208 4,994 8,579 14,772 Other electric revenues (b) 58,209 80,307 26,982 7,263 24,656 Non-customer revenues (c) 3,066 5,400 2,425 1,234 307 Total electric revenues 542,929 1,094,259 302,737 157,152 363,580 Natural gas — 12,058 — 18,641 — Total operating revenues $542,929 $1,106,317 $302,737 $175,793 $363,580 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $159,130 $267,915 $132,730 $58,232 $150,703 Commercial 93,741 221,740 117,351 54,524 94,544 Industrial 97,973 368,678 46,129 9,267 102,771 Governmental 3,766 16,705 11,452 18,448 6,452 Total billed retail 354,610 875,038 307,662 140,471 354,470 Sales for resale (a) 53,195 111,801 11,776 6,190 25,177 Other electric revenues (b) 84,102 70,027 31,696 11,623 23,468 Non-customer revenues (c) 2,698 4,823 2,555 1,318 371 Total electric revenues 494,605 1,061,689 353,689 159,602 403,486 Natural gas — 11,099 — 18,844 — Total operating revenues $494,605 $1,072,788 $353,689 $178,446 $403,486 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2019 and 2018 were as follows: 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $367,581 $554,431 $245,610 $110,697 $294,592 Commercial 250,133 438,912 200,189 99,723 160,125 Industrial 240,491 731,598 76,436 15,740 178,470 Governmental 9,869 34,817 20,557 34,886 10,455 Total billed retail 868,074 1,759,758 542,792 261,046 643,642 Sales for resale (a) 154,085 167,164 9,808 18,803 31,548 Other electric revenues (b) 60,514 92,746 27,387 5,556 28,153 Non-customer revenues (c) 6,068 11,284 4,994 2,630 711 Total electric revenues 1,088,741 2,030,952 584,981 288,035 704,054 Natural gas — 34,695 — 50,952 — Total operating revenues $1,088,741 $2,065,647 $584,981 $338,987 $704,054 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $394,654 $563,433 $281,073 $122,807 $298,828 Commercial 214,375 446,667 227,811 108,796 179,971 Industrial 209,450 721,014 88,629 16,838 186,073 Governmental 8,414 34,015 22,300 36,139 12,433 Total billed retail 826,893 1,765,129 619,813 284,580 677,305 Sales for resale (a) 119,299 201,056 13,769 19,527 48,538 Other electric revenues (b) 94,125 90,529 30,977 8,511 25,733 Non-customer revenues (c) 5,312 10,081 4,873 2,802 850 Total electric revenues 1,045,629 2,066,795 669,432 315,420 752,426 Natural gas — 35,337 — 51,301 — Total operating revenues $1,045,629 $2,102,132 $669,432 $366,721 $752,426 (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)	6 Months Ended
	Jun. 30, 2019
Lease, Cost	Entergy incurred the following total lease costs for the three months ended June 30, 2019: (In Thousands) Operating lease cost $15,255 Financing lease cost: Amortization of right-of-use assets $4,980 Interest on lease liabilities $1,081 Entergy incurred the following total lease costs for the six months ended June 30, 2019: (In Thousands) Operating lease cost $30,976 Financing lease cost: Amortization of right-of-use assets $7,892 Interest on lease liabilities $1,834
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of June 30, 2019: (In Thousands) Current liabilities: Operating leases $51,885 Financing leases $11,177 Non-current liabilities: Operating leases $182,236 Financing leases $53,375
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 June 30, 2019: Weighted average remaining lease terms: Operating leases 5.42 Financing leases 6.94 Weighted average discount rate: Operating leases 3.93 % Financing leases 4.71 %
Lease, Maturity	Maturity of the lease liabilities for Entergy as of June 30, 2019 are as follows: Year Operating Leases Financing Leases (In Thousands) Remainder for 2019 $30,913 $7,067 2020 57,615 13,052 2021 49,126 11,505 2022 40,519 10,307 2023 32,907 9,231 Years thereafter 53,491 25,696 Minimum lease payments 264,571 76,858 Less: amount representing interest 30,450 12,306 Present value of net minimum lease payments $234,121 $64,552
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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,124 $2,824 $1,716 $351 $977 Financing lease cost: Amortization of right-of-use assets $1,198 $1,975 $691 $342 $325 Interest on lease liabilities $198 $299 $117 $55 $53 The Registrant Subsidiaries incurred the following lease costs for the six months ended June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $6,419 $5,850 $3,468 $709 $2,062 Financing lease cost: Amortization of right-of-use assets $1,828 $3,000 $1,039 $518 $630 Interest on lease liabilities $303 $451 $176 $85 $99
Lease, Assets	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $48,567 $33,054 $18,791 $4,172 $12,540 Financing leases $11,167 $16,846 $6,671 $2,991 $5,439
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,374 $9,727 $6,180 $1,218 $3,251 Financing leases $2,408 $3,840 $1,402 $662 $1,240 Non-current liabilities: Operating leases $38,195 $23,333 $12,812 $2,953 $9,375 Financing leases $8,756 $13,000 $5,269 $2,329 $4,112
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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.22 4.27 5.11 4.04 4.52 Financing leases 5.55 5.27 5.42 5.80 5.23 Weighted average discount rate: Operating leases 3.79 % 3.80 % 3.80 % 3.96 % 3.93 % Financing leases 3.78 % 3.78 % 3.77 % 3.95 % 3.89 %
Lease, Maturity	Maturity of the lease liabilities for the Registrant Subsidiaries as of June 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $6,070 $5,419 $3,580 $680 $1,924 2020 11,014 9,797 5,888 1,225 3,776 2021 9,117 8,046 4,759 954 3,026 2022 6,782 5,267 3,338 632 2,061 2023 5,619 3,391 1,237 470 1,704 Years thereafter 15,771 3,777 2,340 693 1,862 Minimum lease payments 54,373 35,697 21,142 4,654 14,353 Less: amount representing interest 5,804 2,637 2,150 483 1,726 Present value of net minimum lease payments $48,569 $33,060 $18,992 $4,171 $12,627 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $1,398 $2,235 $813 $403 $727 2020 2,560 4,032 1,549 645 1,297 2021 2,164 3,377 1,384 535 1,104 2022 1,875 2,937 1,191 484 897 2023 1,648 2,489 977 437 759 Years thereafter 2,698 3,453 1,444 834 1,111 Minimum lease payments 12,343 18,523 7,358 3,338 5,895 Less: amount representing interest 1,179 1,683 687 347 543 Present value of net minimum lease payments $11,164 $16,840 $6,671 $2,991 $5,352
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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,124 $2,824 $1,716 $351 $977 Financing lease cost: Amortization of right-of-use assets $1,198 $1,975 $691 $342 $325 Interest on lease liabilities $198 $299 $117 $55 $53 The Registrant Subsidiaries incurred the following lease costs for the six months ended June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $6,419 $5,850 $3,468 $709 $2,062 Financing lease cost: Amortization of right-of-use assets $1,828 $3,000 $1,039 $518 $630 Interest on lease liabilities $303 $451 $176 $85 $99
Lease, Assets	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $48,567 $33,054 $18,791 $4,172 $12,540 Financing leases $11,167 $16,846 $6,671 $2,991 $5,439
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,374 $9,727 $6,180 $1,218 $3,251 Financing leases $2,408 $3,840 $1,402 $662 $1,240 Non-current liabilities: Operating leases $38,195 $23,333 $12,812 $2,953 $9,375 Financing leases $8,756 $13,000 $5,269 $2,329 $4,112
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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.22 4.27 5.11 4.04 4.52 Financing leases 5.55 5.27 5.42 5.80 5.23 Weighted average discount rate: Operating leases 3.79 % 3.80 % 3.80 % 3.96 % 3.93 % Financing leases 3.78 % 3.78 % 3.77 % 3.95 % 3.89 %
Lease, Maturity	Maturity of the lease liabilities for the Registrant Subsidiaries as of June 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $6,070 $5,419 $3,580 $680 $1,924 2020 11,014 9,797 5,888 1,225 3,776 2021 9,117 8,046 4,759 954 3,026 2022 6,782 5,267 3,338 632 2,061 2023 5,619 3,391 1,237 470 1,704 Years thereafter 15,771 3,777 2,340 693 1,862 Minimum lease payments 54,373 35,697 21,142 4,654 14,353 Less: amount representing interest 5,804 2,637 2,150 483 1,726 Present value of net minimum lease payments $48,569 $33,060 $18,992 $4,171 $12,627 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $1,398 $2,235 $813 $403 $727 2020 2,560 4,032 1,549 645 1,297 2021 2,164 3,377 1,384 535 1,104 2022 1,875 2,937 1,191 484 897 2023 1,648 2,489 977 437 759 Years thereafter 2,698 3,453 1,444 834 1,111 Minimum lease payments 12,343 18,523 7,358 3,338 5,895 Less: amount representing interest 1,179 1,683 687 347 543 Present value of net minimum lease payments $11,164 $16,840 $6,671 $2,991 $5,352
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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,124 $2,824 $1,716 $351 $977 Financing lease cost: Amortization of right-of-use assets $1,198 $1,975 $691 $342 $325 Interest on lease liabilities $198 $299 $117 $55 $53 The Registrant Subsidiaries incurred the following lease costs for the six months ended June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $6,419 $5,850 $3,468 $709 $2,062 Financing lease cost: Amortization of right-of-use assets $1,828 $3,000 $1,039 $518 $630 Interest on lease liabilities $303 $451 $176 $85 $99
Lease, Assets	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $48,567 $33,054 $18,791 $4,172 $12,540 Financing leases $11,167 $16,846 $6,671 $2,991 $5,439
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,374 $9,727 $6,180 $1,218 $3,251 Financing leases $2,408 $3,840 $1,402 $662 $1,240 Non-current liabilities: Operating leases $38,195 $23,333 $12,812 $2,953 $9,375 Financing leases $8,756 $13,000 $5,269 $2,329 $4,112
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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.22 4.27 5.11 4.04 4.52 Financing leases 5.55 5.27 5.42 5.80 5.23 Weighted average discount rate: Operating leases 3.79 % 3.80 % 3.80 % 3.96 % 3.93 % Financing leases 3.78 % 3.78 % 3.77 % 3.95 % 3.89 %
Lease, Maturity	Maturity of the lease liabilities for the Registrant Subsidiaries as of June 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $6,070 $5,419 $3,580 $680 $1,924 2020 11,014 9,797 5,888 1,225 3,776 2021 9,117 8,046 4,759 954 3,026 2022 6,782 5,267 3,338 632 2,061 2023 5,619 3,391 1,237 470 1,704 Years thereafter 15,771 3,777 2,340 693 1,862 Minimum lease payments 54,373 35,697 21,142 4,654 14,353 Less: amount representing interest 5,804 2,637 2,150 483 1,726 Present value of net minimum lease payments $48,569 $33,060 $18,992 $4,171 $12,627 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $1,398 $2,235 $813 $403 $727 2020 2,560 4,032 1,549 645 1,297 2021 2,164 3,377 1,384 535 1,104 2022 1,875 2,937 1,191 484 897 2023 1,648 2,489 977 437 759 Years thereafter 2,698 3,453 1,444 834 1,111 Minimum lease payments 12,343 18,523 7,358 3,338 5,895 Less: amount representing interest 1,179 1,683 687 347 543 Present value of net minimum lease payments $11,164 $16,840 $6,671 $2,991 $5,352
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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,124 $2,824 $1,716 $351 $977 Financing lease cost: Amortization of right-of-use assets $1,198 $1,975 $691 $342 $325 Interest on lease liabilities $198 $299 $117 $55 $53 The Registrant Subsidiaries incurred the following lease costs for the six months ended June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $6,419 $5,850 $3,468 $709 $2,062 Financing lease cost: Amortization of right-of-use assets $1,828 $3,000 $1,039 $518 $630 Interest on lease liabilities $303 $451 $176 $85 $99
Lease, Assets	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $48,567 $33,054 $18,791 $4,172 $12,540 Financing leases $11,167 $16,846 $6,671 $2,991 $5,439
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,374 $9,727 $6,180 $1,218 $3,251 Financing leases $2,408 $3,840 $1,402 $662 $1,240 Non-current liabilities: Operating leases $38,195 $23,333 $12,812 $2,953 $9,375 Financing leases $8,756 $13,000 $5,269 $2,329 $4,112
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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.22 4.27 5.11 4.04 4.52 Financing leases 5.55 5.27 5.42 5.80 5.23 Weighted average discount rate: Operating leases 3.79 % 3.80 % 3.80 % 3.96 % 3.93 % Financing leases 3.78 % 3.78 % 3.77 % 3.95 % 3.89 %
Lease, Maturity	Maturity of the lease liabilities for the Registrant Subsidiaries as of June 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $6,070 $5,419 $3,580 $680 $1,924 2020 11,014 9,797 5,888 1,225 3,776 2021 9,117 8,046 4,759 954 3,026 2022 6,782 5,267 3,338 632 2,061 2023 5,619 3,391 1,237 470 1,704 Years thereafter 15,771 3,777 2,340 693 1,862 Minimum lease payments 54,373 35,697 21,142 4,654 14,353 Less: amount representing interest 5,804 2,637 2,150 483 1,726 Present value of net minimum lease payments $48,569 $33,060 $18,992 $4,171 $12,627 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $1,398 $2,235 $813 $403 $727 2020 2,560 4,032 1,549 645 1,297 2021 2,164 3,377 1,384 535 1,104 2022 1,875 2,937 1,191 484 897 2023 1,648 2,489 977 437 759 Years thereafter 2,698 3,453 1,444 834 1,111 Minimum lease payments 12,343 18,523 7,358 3,338 5,895 Less: amount representing interest 1,179 1,683 687 347 543 Present value of net minimum lease payments $11,164 $16,840 $6,671 $2,991 $5,352
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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $3,124 $2,824 $1,716 $351 $977 Financing lease cost: Amortization of right-of-use assets $1,198 $1,975 $691 $342 $325 Interest on lease liabilities $198 $299 $117 $55 $53 The Registrant Subsidiaries incurred the following lease costs for the six months ended June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating lease cost $6,419 $5,850 $3,468 $709 $2,062 Financing lease cost: Amortization of right-of-use assets $1,828 $3,000 $1,039 $518 $630 Interest on lease liabilities $303 $451 $176 $85 $99
Lease, Assets	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Operating leases $48,567 $33,054 $18,791 $4,172 $12,540 Financing leases $11,167 $16,846 $6,671 $2,991 $5,439
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $10,374 $9,727 $6,180 $1,218 $3,251 Financing leases $2,408 $3,840 $1,402 $662 $1,240 Non-current liabilities: Operating leases $38,195 $23,333 $12,812 $2,953 $9,375 Financing leases $8,756 $13,000 $5,269 $2,329 $4,112
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 June 30, 2019: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 6.22 4.27 5.11 4.04 4.52 Financing leases 5.55 5.27 5.42 5.80 5.23 Weighted average discount rate: Operating leases 3.79 % 3.80 % 3.80 % 3.96 % 3.93 % Financing leases 3.78 % 3.78 % 3.77 % 3.95 % 3.89 %
Lease, Maturity	Maturity of the lease liabilities for the Registrant Subsidiaries as of June 30, 2019 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $6,070 $5,419 $3,580 $680 $1,924 2020 11,014 9,797 5,888 1,225 3,776 2021 9,117 8,046 4,759 954 3,026 2022 6,782 5,267 3,338 632 2,061 2023 5,619 3,391 1,237 470 1,704 Years thereafter 15,771 3,777 2,340 693 1,862 Minimum lease payments 54,373 35,697 21,142 4,654 14,353 Less: amount representing interest 5,804 2,637 2,150 483 1,726 Present value of net minimum lease payments $48,569 $33,060 $18,992 $4,171 $12,627 Financing Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Remainder of 2019 $1,398 $2,235 $813 $403 $727 2020 2,560 4,032 1,549 645 1,297 2021 2,164 3,377 1,384 535 1,104 2022 1,875 2,937 1,191 484 897 2023 1,648 2,489 977 437 759 Years thereafter 2,698 3,453 1,444 834 1,111 Minimum lease payments 12,343 18,523 7,358 3,338 5,895 Less: amount representing interest 1,179 1,683 687 347 543 Present value of net minimum lease payments $11,164 $16,840 $6,671 $2,991 $5,352
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)	6 Months Ended
	Jun. 30, 2019
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

Aug. 31, 2019

Jun. 30, 2019

May 31, 2019

Apr. 30, 2019

Jan. 31, 2019

Jul. 31, 2018

Jun. 30, 2019

Jun. 30, 2018

Dec. 31, 2020

Mar. 31, 2020

Dec. 31, 2019

Mar. 31, 2019

Dec. 31, 2018

Jul. 27, 2019

Apr. 23, 2018

Regulatory Assets [Line Items]

Impairment of Long-Lived Assets Held-for-use

$ 26,684,000

$ 51,503,000

Deferred Fuel Cost

$ 8,685,000

8,685,000

$ 27,251,000

Entergy Louisiana [Member]

Regulatory Assets [Line Items]

Deferred Fuel Cost

8,685,000

8,685,000

$ 0

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 Mississippi [Member]

Regulatory Assets [Line Items]

Deferred Fuel Cost

0

$ 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

True-up to provision recorded to reflect change in formula rate plan revenues compared to allowed rate of return

900,000

900,000

$ 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] | Subsequent Event [Member]

Regulatory Assets [Line Items]

Public Utilities, Requested Rate Increase (Decrease), Amount

$ 30,000,000

Entergy New Orleans [Member] | Subsequent Event [Member] | Electricity [Member]

Regulatory Assets [Line Items]

Public Utilities, Requested Rate Increase (Decrease), Amount

27,000,000

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

10.50%

Entergy Texas [Member]

Regulatory Assets [Line Items]

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 Arkansas [Member]

Regulatory Assets [Line Items]

Deferred Fuel Cost

0

0

19,235,000

Refund to Customers Credited Through Formula Rate Plan

46,600,000

Energy Cost Recovery Rider Rate Per kWh

$ 0.01882

Retail balance over-recovery

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

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 Return on Equity, Percentage

9.75%

Public Utilities, Requested Rate Increase (Decrease), Amount

$ 15,300,000

Projected Revenue Deficiency

$ 61,900,000

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%

LPSC requested authorized return on equity for System Energy in return on equity proceeding

7.81%

APSC/MPSC requested authorized return on equity for System Energy in return on equity proceeding

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

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

System Energy [Member] | Minimum [Member]

Regulatory Assets [Line Items]

Public Utilities, Requested Return on Equity, Percentage

10.10%

System Energy [Member] | Maximum [Member]

Regulatory Assets [Line Items]

Public Utilities, Requested Return on Equity, Percentage

10.70%

System Energy [Member] | Subsequent Event [Member]

Regulatory Assets [Line Items]

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%

APSC/MPSC requested authorized return on equity for System Energy in return on equity proceeding

8.41%

System Energy [Member] | Subsequent Event [Member] | Minimum [Member]

Regulatory Assets [Line Items]

Public Utilities, Requested Return on Equity, Percentage

10.32%

System Energy [Member] | Subsequent Event [Member] | Maximum [Member]

Regulatory Assets [Line Items]

Public Utilities, Requested Return on Equity, Percentage

10.69%

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] | Subsequent Event [Member]

Regulatory Assets [Line Items]

Public Utilities, Requested Rate Increase (Decrease), Amount

3,200,000

Transmission Cost Recovery Factor Rider [Member] | Entergy Texas [Member] | Subsequent Event [Member]

Regulatory Assets [Line Items]

Public Utilities, Requested Rate Increase (Decrease), Amount

2,700,000

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	Jul. 26, 2019	May 31, 2019	Dec. 31, 2018	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Jan. 01, 2019	Jan. 01, 2018
Equity [Abstract]
Stock Options Excluded From Diluted Common Shares Outstanding Calculation					1,100,000	300,000	1,100,000
Forward Contract Indexed to Issuer's Equity, Indexed Shares					15,300,000		15,300,000
Proceeds from Issuance of Common Stock		$ 608,000	$ 500,000			$ 607,650	$ 0
Shares, Issued				1,181,800		1,181,800
Common stock dividend (in dollars per share)				$ 0.91	$ 0.89	$ 1.82	$ 1.78
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)	$ 0.91

Equity (Schedule Of Earnings Pe

Equity (Schedule Of Earnings Per Share, Basic And Diluted) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Incremental Weighted Average Shares Attributable to Dilutive Effect [Abstract]
Stock options, Shares	500,000	300,000	500,000	300,000
Stock options $/share	$ 0	$ 0	$ (0.01)	$ 0
Restricted stock, Shares	700,000	700,000	600,000	500,000
Restricted stock $/share	$ 0	$ (0.01)	$ (0.01)	$ 0
Incremental Common Shares Attributable to Dilutive Effect of Equity Forward Agreements	0	1,200,000	800,000	600,000
Average Dilutive Effect Of Equity Forwards	$ 0	$ (0.01)	$ (0.01)	$ (0.01)
Basic earnings per share
Net income (loss) attributable to Entergy Corporation, Income	$ 236,424	$ 245,421	$ 490,961	$ 378,181
Net Income (Loss) Available to Common Stockholders, Diluted	$ 236,400	$ 245,400	$ 491,000	$ 378,200
Net Income Attributable to Entergy Corporation, Shares	193,019,269	180,823,203	191,306,742	180,765,708
Net Income Attributable to Entergy Corporation, $/share	$ 1.22	$ 1.36	$ 2.57	$ 2.09
Diluted earnings per share, Shares	194,238,315	182,982,630	193,243,287	182,208,328
Diluted earnings per share $/share	$ 1.22	$ 1.34	$ 2.54	$ 2.08

Equity (Accumulated Other Compr

Equity (Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Mar. 31, 2019	Jan. 01, 2019	Dec. 31, 2018	Mar. 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	$ (430,404)	$ (613,642)	$ (430,404)	$ (613,642)	$ (551,152)		$ (557,173)	$ (561,498)		$ (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	115,193	(70,490)	157,043	(35,200)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	5,555	18,346	(23,468)	62,201
Other comprehensive income (loss)	120,748	(52,144)	133,575	27,001
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	26,736	(8,842)	26,736	(8,842)	12,466		(2,116)	(6,201)		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	15,834	(7,509)	29,373	(43,785)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(1,564)	4,868	(1,400)	8,288
Other comprehensive income (loss)	14,270	(2,641)	27,973	(35,497)
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)			133,575	27,001
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	(508,876)	(589,926)	(508,876)	(589,926)	(520,372)		(531,922)	(605,491)		(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	11,496	15,565	23,046	32,139
Other comprehensive income (loss)	11,496	15,565	23,046	32,139
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	51,736	(14,874)	51,736	(14,874)	(43,246)		(23,135)	50,194		(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	99,359	(62,981)	127,670	8,585
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(4,377)	(2,087)	(45,114)	21,774
Other comprehensive income (loss)	94,982	(65,068)	82,556	30,359
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	(8,091)		(8,091)				(6,153)
Other comprehensive income (loss)	(969)	(501)	(1,938)	(1,002)
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)			(1,938)	(1,002)
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	(8,091)	(57,451)	(8,091)	(57,451)	$ (7,122)		$ (6,153)	$ (56,950)		$ (46,400)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(969)	(501)	(1,938)	(1,002)
Other comprehensive income (loss)	$ (969)	$ (501)	(1,938)	(1,002)
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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,666,209	$ 2,668,770	$ 5,275,792	$ 5,392,650
Other Nonoperating Income (Expense)	(45,870)	(48,491)	(110,527)	(79,849)
Income taxes (benefits)	(1,458)	280,596	(44,229)	236,933
Consolidated net income	240,533	248,860	499,180	385,059
Competitive Businesses [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	289,783	308,602	723,394	727,526
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Consolidated net income	(5,555)	(18,346)	23,468	(62,201)
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)	(93)	(97)	(215)
INCOME (LOSS) BEFORE INCOME TAXES	5,541	2,642	57,107	(27,562)
Income taxes (benefits)	(1,164)	(555)	(11,993)	5,788
Consolidated net income	4,377	2,087	45,114	(21,774)
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	5,589	2,735	57,204	(27,347)
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)	2,475	(7,702)	2,216	(13,114)
Income taxes (benefits)	(911)	2,834	(816)	4,826
Consolidated net income	1,564	(4,868)	1,400	(8,288)
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	5,424	10,652	10,850
Amortization of loss	(18,980)	(24,808)	(37,969)	(49,760)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	(918)	(406)	(2,055)	(2,022)
INCOME (LOSS) BEFORE INCOME TAXES	(14,573)	(19,790)	(29,372)	(40,932)
Income taxes (benefits)	3,077	4,225	6,326	8,793
Consolidated net income	(11,496)	(15,565)	(23,046)	(32,139)
Entergy Louisiana [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,106,317	1,072,788	2,065,647	2,102,132
Other Nonoperating Income (Expense)	(22,306)	(22,770)	(64,650)	(30,435)
Income taxes (benefits)	(38,405)	55,122	(54,936)	33,374
Consolidated net income	183,084	184,358	310,717	295,952
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	3,674	3,868
Amortization of loss	(526)	(1,256)	(1,052)	(2,513)
INCOME (LOSS) BEFORE INCOME TAXES	1,311	678	2,622	1,355
Income taxes (benefits)	(342)	(177)	(684)	(353)
Consolidated net income	$ 969	$ 501	$ 1,938	$ 1,002

Revolving Credit Facilities, _3

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Narrative) (Details) - USD ($)	Sep. 16, 2021	Jun. 30, 2019	Mar. 31, 2019	Feb. 28, 2019	Jan. 31, 2019	Jun. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Short-term borrowings		$ 1,635,462,000				$ 1,635,462,000	$ 1,942,339,000
Amount of Facility		3,500,000,000				3,500,000,000
Amount Drawn/ Outstanding		$ 150,000,000				$ 150,000,000
Commercial Paper Program [Member]
Debt Instrument [Line Items]
Debt, weighted average interest rate		2.97%				2.97%
Commercial Paper program limit		$ 2,000,000,000				$ 2,000,000,000
Commercial Paper Amount Outstanding		1,635,000,000				1,635,000,000
Credit Facility [Member]
Debt Instrument [Line Items]
Amount of Facility		3,500,000,000				3,500,000,000
Amount of total borrowing capacity against which fronting commitments exist		20,000,000				$ 20,000,000
Line of credit facility, commitment fee percentage						0.225%
Line of Credit Facility, Interest Rate During Period						4.05%
Entergy Arkansas [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		250,000,000				$ 250,000,000
Amount of total borrowing capacity against which fronting commitments exist		5,000,000				5,000,000
Entergy Arkansas [Member] | Mortgage Bonds Four Point Two Percent Series Due April 2049 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt			$ 350,000,000
Debt instrument, interest rate, stated percentage			4.20%
Entergy Louisiana [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		450,000,000				450,000,000
Amount of total borrowing capacity against which fronting commitments exist		15,000,000				15,000,000
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			$ 525,000,000
Debt instrument, interest rate, stated percentage			4.20%
Entergy Mississippi [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		175,000,000				175,000,000
Letters of Credit Outstanding, Amount		200,000				$ 200,000	200,000
Entergy Mississippi [Member] | Mortgage bonds, 3.85% Series due June 2049 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt		$ 300,000,000
Debt instrument, interest rate, stated percentage		3.85%				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%				6.64%
Repayments of Debt		$ 150,000,000
Entergy Texas [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		200,000,000				$ 200,000,000
Amount of total borrowing capacity against which fronting commitments exist		30,000,000				30,000,000
Letters of Credit Outstanding, Amount		2,200,000				2,200,000	$ 4,100,000
Entergy Texas [Member] | Mortgage Bonds Four Percent Due March 2029 [Domain]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt					$ 300,000,000
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					$ 400,000,000
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				$ 500,000,000
System Energy [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		200,000,000				200,000,000
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			$ 134,000,000
Debt instrument, interest rate, stated percentage			2.50%
Entergy Nuclear Vermont Yankee [Member]
Debt Instrument [Line Items]
Amount of Facility		139,000,000				$ 139,000,000
Line of credit facility, commitment fee percentage						0.20%
Amount Drawn/ Outstanding		139,000,000			$ 139,000,000	$ 139,000,000
Line of Credit Facility, Interest Rate During Period						4.19%
Entergy New Orleans [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		150,000,000				$ 150,000,000
Amount of total borrowing capacity against which fronting commitments exist		10,000,000				10,000,000
Letters of Credit Outstanding, Amount		10,200				10,200
System Energy VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		74,400,000				$ 74,400,000
Line of Credit Facility, Interest Rate During Period						3.40%
Line of credit facility commitment fee as a percentage of undrawn commitment amount						0.10%
System Energy VIE [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			$ 134,000,000
Entergy Arkansas VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		$ 20,600,000				$ 20,600,000
Line of Credit Facility, Interest Rate During Period						3.40%
Line of credit facility commitment fee as a percentage of undrawn commitment amount						0.10%
Entergy Arkansas VIE [Member] | Three Point Six Five Percent Series L Notes Due July Two Thousand Twenty One [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		3.65%				3.65%
Entergy Louisiana Waterford VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		$ 79,200,000				$ 79,200,000
Line of Credit Facility, Interest Rate During Period						3.40%
Line of credit facility commitment fee as a percentage of undrawn commitment amount						0.10%
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		$ 87,500,000				$ 87,500,000
Line of Credit Facility, Interest Rate During Period						3.40%
Line of credit facility commitment fee as a percentage of undrawn commitment amount						0.10%
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		$ 20,000,000				$ 20,000,000
Letters of Credit Outstanding, Amount		0				0
Amount Drawn/ Outstanding		0				$ 0
Line of Credit Facility, Interest Rate During Period						3.57%
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		350,000,000				$ 350,000,000
Letters of Credit Outstanding, Amount		0				0
Amount Drawn/ Outstanding		0				$ 0
Line of Credit Facility, Interest Rate During Period						3.57%
Line of Credit Facility, Expiration Date						Sep. 14, 2023
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Amount of Facility		150,000,000				$ 150,000,000
Letters of Credit Outstanding, Amount		0				0
Amount Drawn/ Outstanding		0				$ 0
Line of Credit Facility, Interest Rate During Period						3.57%
Line of Credit Facility, Expiration Date						Sep. 14, 2023
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Amount of Facility		150,000,000				$ 150,000,000
Letters of Credit Outstanding, Amount		1,300,000				1,300,000
Amount Drawn/ Outstanding		0				$ 0
Line of Credit Facility, Interest Rate During Period						3.82%
Line of Credit Facility, Expiration Date						Sep. 14, 2023
Credit Facility Of Thirty Seven Point Five Million [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Amount of Facility		37,500,000				$ 37,500,000
Letters of Credit Outstanding, Amount		0				0
Amount Drawn/ Outstanding		0				$ 0
Line of Credit Facility, Interest Rate During Period						3.82%
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		35,000,000				$ 35,000,000
Letters of Credit Outstanding, Amount		0				0
Amount Drawn/ Outstanding		0				$ 0
Line of Credit Facility, Interest Rate During Period						3.82%
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		10,000,000				$ 10,000,000
Letters of Credit Outstanding, Amount		0				0
Amount Drawn/ Outstanding		0				$ 0
Line of Credit Facility, Interest Rate During Period						3.82%
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		25,000,000				$ 25,000,000
Letters of Credit Outstanding, Amount		800,000				800,000
Amount Drawn/ Outstanding		$ 0				$ 0
Line of Credit Facility, Interest Rate During Period						3.59%
Line of Credit Facility, Expiration Date						Nov. 20, 2021
Subsequent Event [Member] | System Energy VIE [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Expiration Date	Sep. 16, 2021
Subsequent Event [Member] | Entergy Arkansas VIE [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Expiration Date	Sep. 16, 2021
Subsequent Event [Member] | Entergy Louisiana Waterford VIE [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Expiration Date	Sep. 16, 2021
Subsequent Event [Member] | Entergy Louisiana River Bend VIE [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Expiration Date	Sep. 16, 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	Jun. 30, 2019USD ($)
Summary of the borrowings outstanding and capacity available under the facility
Capacity	$ 3,500
Amount Drawn/ Outstanding	150
Letters of Credit	6
Capacity Available	$ 3,344

Revolving Credit Facilities, _5

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Credit Facilities) (Details) - USD ($)	6 Months Ended
	Jun. 30, 2019	Dec. 31, 2018
Amount of Facility	$ 3,500,000,000
Amount Drawn/ Outstanding	150,000,000
Entergy Arkansas [Member]
Amount of total borrowing capacity against which fronting commitments exist	$ 5,000,000
Entergy Arkansas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Sep. 14, 2023
Amount of Facility	$ 150,000,000
Interest Rate	3.57%
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	$ 20,000,000
Interest Rate	3.57%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Louisiana [Member]
Amount of total borrowing capacity against which fronting commitments exist	$ 15,000,000
Entergy Louisiana [Member] | Credit Facility Of Three Hundred Fifty Million [Member]
Expiration Date	Sep. 14, 2023
Amount of Facility	$ 350,000,000
Interest Rate	3.57%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	$ 200,000	$ 200,000
Entergy Mississippi [Member] | Credit Facility Of Thirty Seven Point Five Million [Member]
Expiration Date	May 31, 2020
Amount of Facility	$ 37,500,000
Interest Rate	3.82%
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	$ 35,000,000
Interest Rate	3.82%
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	$ 10,000,000
Interest Rate	3.82%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy New Orleans [Member]
Amount of total borrowing capacity against which fronting commitments exist	10,000,000
Letters of Credit Outstanding, Amount	$ 10,200
Entergy New Orleans [Member] | Credit Facility Of Twenty Five Million [Member]
Expiration Date	Nov. 20, 2021
Amount of Facility	$ 25,000,000
Interest Rate	3.59%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	800,000
Entergy Texas [Member]
Amount of total borrowing capacity against which fronting commitments exist	30,000,000
Letters of Credit Outstanding, Amount	$ 2,200,000	$ 4,100,000
Entergy Texas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Sep. 14, 2023
Amount of Facility	$ 150,000,000
Interest Rate	3.82%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 1,300,000

Revolving Credit Facilities, _6

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Short-Term Borrowings And The Outstanding Short-Term Borrowings) (Details) $ in Millions	Jun. 30, 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	36
Entergy Texas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	169
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) - USD ($) $ in Millions	Sep. 16, 2021	Jun. 30, 2019
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount Drawn/ Outstanding		$ 150
Entergy Arkansas VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount of Facility		$ 80
Line of Credit Facility, Interest Rate During Period		3.40%
Amount Drawn/ Outstanding		$ 20.6
Line of credit facility commitment fee as a percentage of undrawn commitment amount		0.10%
Entergy Arkansas VIE [Member] | Subsequent Event [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Sep. 16, 2021
System Energy VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount of Facility		$ 120
Line of Credit Facility, Interest Rate During Period		3.40%
Amount Drawn/ Outstanding		$ 74.4
Line of credit facility commitment fee as a percentage of undrawn commitment amount		0.10%
System Energy VIE [Member] | Subsequent Event [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Sep. 16, 2021
Entergy Louisiana River Bend VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount of Facility		$ 105
Line of Credit Facility, Interest Rate During Period		3.40%
Amount Drawn/ Outstanding		$ 87.5
Line of credit facility commitment fee as a percentage of undrawn commitment amount		0.10%
Entergy Louisiana River Bend VIE [Member] | Subsequent Event [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Sep. 16, 2021
Entergy Louisiana Waterford VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount of Facility		$ 105
Line of Credit Facility, Interest Rate During Period		3.40%
Amount Drawn/ Outstanding		$ 79.2
Line of credit facility commitment fee as a percentage of undrawn commitment amount		0.10%
Entergy Louisiana Waterford VIE [Member] | Subsequent Event [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Sep. 16, 2021

Revolving Credit Facilities, _8

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Notes Payable By Variable Interest Entities) (Details) $ in Millions	Jun. 30, 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	Jun. 30, 2019	Dec. 31, 2018
Long-term Debt, Fair Value	$ 18,126,143	$ 15,880,239
Long-term Debt, Book Value	17,354,298	16,168,312
Entergy Arkansas [Member]
Long-term Debt, Fair Value	3,523,519	3,002,627
Long-term Debt, Book Value	3,527,146	3,225,759
Long term DOE obligations	189,000	187,000
Entergy Louisiana [Member]
Long-term Debt, Fair Value	7,892,133	6,834,134
Long-term Debt, Book Value	7,359,935	6,805,768
Entergy Mississippi [Member]
Long-term Debt, Fair Value	1,680,869	1,276,452
Long-term Debt, Book Value	1,619,420	1,325,750
Entergy New Orleans [Member]
Long-term Debt, Fair Value	511,691	491,569
Long-term Debt, Book Value	478,514	483,704
Entergy Texas [Member]
Long-term Debt, Fair Value	1,786,350	1,528,828
Long-term Debt, Book Value	1,664,936	1,513,735
System Energy [Member]
Long-term Debt, Fair Value	571,693	596,123
Long-term Debt, Book Value	590,646	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 ($)	Jun. 30, 2019	Dec. 31, 2018
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	$ 200,000	$ 200,000
Entergy New Orleans [Member]
Letters of Credit Outstanding, Amount	10,200
Entergy Texas [Member]
Letters of Credit Outstanding, Amount	2,200,000	$ 4,100,000
Credit Facility Of Twenty Five Million [Member] | Entergy Arkansas [Member]
Uncommitted Credit Facility	$ 25,000,000
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 1,000,000
Credit Facility of Fifty Million [Member] | Entergy Texas [Member]
Uncommitted Credit Facility	$ 50,000,000
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 29,500,000
Credit Facility of Forty Million [Member] | Entergy Mississippi [Member]
Uncommitted Credit Facility	$ 40,000,000
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 10,900,000
Credit Facility of Fifteen Million [Member] | Entergy New Orleans [Member]
Uncommitted Credit Facility	$ 15,000,000
Letter of Credit Fee, Percentage	1.00%
Letters of Credit Outstanding, Amount	$ 1,000,000
Credit Facility Of One Hundred Twenty Five Million [Member] | Entergy Louisiana [Member]
Uncommitted Credit Facility	$ 125,000,000
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 37,800,000

Stock Based Compensation (Narra

Stock Based Compensation (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	3 Months Ended	6 Months Ended
	Jan. 31, 2019	Mar. 31, 2019	Jun. 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			2,912,294
Weighted-average exercise price of stock options outstanding (in dollars per share)			$ 78.64
Intrinsic value in the money stock options			$ 70.8
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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 1	$ 1.1	$ 2	$ 2.2
Tax benefit recognized in Entergy's net income	0.3	0.3	0.5	0.6
Compensation cost capitalized as part of fixed assets and inventory	$ 0.3	$ 0.2	$ 0.6	$ 0.4

Stock-Based Compensation (Fin_2

Stock-Based Compensation (Financial Information For Other Equity Plans) (Details) - Other Equity Awards [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 8.4	$ 8.7	$ 17.2	$ 17.5
Tax benefit recognized in Entergy's net income	2.2	2.2	4.4	4.4
Compensation cost capitalized as part of fixed assets and inventory	$ 2.9	$ 2.5	$ 5.8	$ 4.8

Retirement And Other Postreti_3

Retirement And Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2019	Jun. 30, 2019	Jun. 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				65,500
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				9,338
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				10,093
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				2,671
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				674
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				739
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				2,944
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			$ 17,774
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			16,358
Subsequent Event [Member] | Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			5,030
Subsequent Event [Member] | Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			1,126
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			906
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			$ 5,341
Non Qualified Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	7,600	$ 6,600		11,600	$ 15,500
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits	3,700	2,400		3,700	6,800
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	71	122		144	254
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits		10			22
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	41	46		84	96
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	113	77		188	157
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits	40			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	6	21		11	42
Non Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	$ 122	270		$ 246	407
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits		$ 139			$ 139

Retirement And Other Postreti_4

Retirement And Other Postretirement Benefits (Components Of Qualified Net Pension Cost) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	$ 33,606	$ 38,752	$ 67,213	$ 77,504
Interest cost on projected benefit obligation	73,912	66,854	147,853	133,708
Expected return on assets	(103,859)	(110,535)	(207,743)	(221,070)
Amortization of prior service cost (credit)	0	99	0	198
Amortization of loss	58,420	68,526	116,838	137,052
Net other postretirement benefit cost	62,241	63,696	125,460	127,392
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	162	0	1,299	0
Pension Plans Defined Benefit [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	5,261	6,189	10,522	12,378
Interest cost on projected benefit obligation	14,175	13,004	28,350	26,008
Expected return on assets	(20,176)	(21,851)	(40,352)	(43,702)
Amortization of loss	11,841	13,412	23,682	26,824
Net other postretirement benefit cost	11,101	10,754	22,202	21,508
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	14,568	16,892
Interest cost on projected benefit obligation	15,882	14,940	31,764	29,880
Expected return on assets	(22,652)	(24,809)	(45,304)	(49,618)
Amortization of loss	11,643	14,450	23,286	28,900
Net other postretirement benefit cost	12,157	13,027	24,314	26,054
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	3,258	3,644
Interest cost on projected benefit obligation	4,068	3,769	8,136	7,538
Expected return on assets	(5,968)	(6,502)	(11,936)	(13,004)
Amortization of loss	3,105	3,610	6,209	7,220
Net other postretirement benefit cost	2,834	2,699	5,667	5,398
Pension Plans Defined Benefit [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	569	673	1,138	1,346
Interest cost on projected benefit obligation	1,874	1,813	3,748	3,626
Expected return on assets	(2,697)	(2,993)	(5,393)	(5,986)
Amortization of loss	1,530	1,954	3,059	3,908
Net other postretirement benefit cost	1,276	1,447	2,552	2,894
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	2,700	3,178
Interest cost on projected benefit obligation	3,612	3,348	7,224	6,696
Expected return on assets	(5,862)	(6,523)	(11,724)	(13,046)
Amortization of loss	2,334	2,626	4,668	5,252
Net other postretirement benefit cost	1,434	1,040	2,868	2,080
Pension Plans Defined Benefit [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,550	1,776	3,100	3,552
Interest cost on projected benefit obligation	3,363	3,227	6,727	6,454
Expected return on assets	(4,677)	(4,991)	(9,354)	(9,982)
Amortization of loss	2,850	3,715	5,700	7,430
Net other postretirement benefit cost	3,086	3,727	6,173	7,454
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	4,675	6,782	9,350	13,564
Interest cost on projected benefit obligation	11,975	12,681	23,950	25,362
Expected return on assets	(9,562)	(10,373)	(19,124)	(20,746)
Amortization of prior service cost (credit)	(8,844)	(9,251)	(17,688)	(18,502)
Amortization of loss	358	3,432	716	6,864
Net other postretirement benefit cost	(1,398)	3,271	(2,796)	6,542
Other Postretirement [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	591	793	1,182	1,586
Interest cost on projected benefit obligation	1,807	1,997	3,614	3,994
Expected return on assets	(3,991)	(4,342)	(7,982)	(8,684)
Amortization of prior service cost (credit)	(1,238)	(1,278)	(2,476)	(2,556)
Amortization of loss	144	289	288	578
Net other postretirement benefit cost	(2,687)	(2,541)	(5,374)	(5,082)
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,160	1,556	2,320	3,112
Interest cost on projected benefit obligation	2,666	2,789	5,332	5,578
Expected return on assets	0	0	0	0
Amortization of prior service cost (credit)	(1,837)	(1,934)	(3,674)	(3,868)
Amortization of loss	(174)	388	(348)	776
Net other postretirement benefit cost	1,815	2,799	3,630	5,598
Other Postretirement [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	262	321	524	642
Interest cost on projected benefit obligation	670	683	1,340	1,366
Expected return on assets	(1,199)	(1,303)	(2,398)	(2,606)
Amortization of prior service cost (credit)	(439)	(456)	(878)	(912)
Amortization of loss	181	377	362	754
Net other postretirement benefit cost	(525)	(378)	(1,050)	(756)
Other Postretirement [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	92	129	184	258
Interest cost on projected benefit obligation	395	417	790	834
Expected return on assets	(1,237)	(1,313)	(2,474)	(2,626)
Amortization of prior service cost (credit)	(171)	(186)	(342)	(372)
Amortization of loss	58	34	116	68
Net other postretirement benefit cost	(863)	(919)	(1,726)	(1,838)
Other Postretirement [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	236	330	472	660
Interest cost on projected benefit obligation	854	939	1,708	1,878
Expected return on assets	(2,276)	(2,446)	(4,552)	(4,892)
Amortization of prior service cost (credit)	(561)	(579)	(1,122)	(1,158)
Amortization of loss	121	206	242	412
Net other postretirement benefit cost	(1,626)	(1,550)	(3,252)	(3,100)
Other Postretirement [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	243	306	486	612
Interest cost on projected benefit obligation	476	500	952	1,000
Expected return on assets	(697)	(783)	(1,394)	(1,566)
Amortization of prior service cost (credit)	(363)	(378)	(726)	(756)
Amortization of loss	89	233	178	466
Net other postretirement benefit cost	(252)	(122)	(504)	(244)
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	7,600	6,600	11,600	15,500
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits	3,700	2,400	3,700	6,800
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	71	122	144	254
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits		10		22
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	41	46	84	96
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	113	77	188	157
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits	40		40
Non Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	6	21	11	42
Non Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	$ 122	270	$ 246	407
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits		$ 139		$ 139

Retirement And Other Postreti_5

Retirement And Other Postretirement Benefits (Expected Employer Contributions) (Details) - USD ($) $ in Thousands	6 Months Ended
	Dec. 31, 2019	Jun. 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		65,500
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		10,093
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	$ 16,358
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		2,671
Entergy Mississippi [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	5,030
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		674
Entergy New Orleans [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	1,126
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		739
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	906
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		2,944
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	5,341
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		$ 9,338
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	$ 17,774

Retirement And Other Postreti_6

Retirement And Other Postretirement Benefits (Reclassification Out Of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	$ 5,325	$ 5,424	$ 10,652	$ 10,850
Amortization of loss	(18,980)	(24,808)	(37,969)	(49,760)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(918)	(406)	(2,055)	(2,022)
Total	(14,573)	(19,790)	(29,372)	(40,932)
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,837	1,934	3,674	3,868
Amortization of loss	(526)	(1,256)	(1,052)	(2,513)
Total	1,311	678	2,622	1,355
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	(99)	0	(198)
Amortization of loss	(18,736)	(21,957)	(37,470)	(43,914)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(162)	0	(1,299)	0
Total	(18,898)	(22,056)	(38,769)	(44,112)
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)	(1,397)	(1,734)
Total	(699)	(867)	(1,397)	(1,734)
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	5,375	5,594	10,750	11,189
Amortization of loss	308	(1,933)	615	(3,865)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0	0	0	0
Total	5,683	3,661	11,365	7,324
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,837	1,934	3,674	3,868
Amortization of loss	174	(387)	348	(775)
Total	2,011	1,547	4,022	3,093
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(50)	(71)	(98)	(141)
Amortization of loss	(552)	(918)	(1,114)	(1,981)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(756)	(406)	(756)	(2,022)
Total	(1,358)	(1,395)	(1,968)	(4,144)
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)	(3)	(4)
Total	$ (1)	$ (2)	$ (3)	$ (4)

Business Segment Information Bu

Business Segment Information Business Segment Information (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended	29 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2019	Jun. 01, 2022
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Asset Write-Offs, Impairments, And Related Charges	$ 16	$ 69	$ 90	$ 142
Restructuring Charges	22	34	56	60
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges			56
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | Subsequent Event [Member]
Segment Reporting Information [Line Items]
Restructuring Charges					$ 120	$ 120
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	$ 22	$ 34	$ 56	$ 60

Business Segment Information (S

Business Segment Information (Segment Financial Information) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,666,209	$ 2,668,770	$ 5,275,792	$ 5,392,650
Segment Financial Information
Income taxes (benefits)	1,458	(280,596)	44,229	(236,933)
Consolidated net income	240,533	248,860	499,180	385,059
Assets	50,565,745		50,565,745		$ 48,275,066
Utility [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,376,437	2,360,208	4,552,419	4,665,197
Segment Financial Information
Income taxes (benefits)	21,150	(240,324)	9,586	(188,100)
Consolidated net income	334,752	378,394	568,900	596,333
Assets	47,297,832		47,297,832		44,777,167
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	289,783	308,602	723,394	727,526
Segment Financial Information
Income taxes (benefits)	(9,290)	(30,144)	56,618	(31,222)
Consolidated net income	(25,382)	(56,337)	71,697	(74,116)
Assets	5,211,771		5,211,771		5,459,275
All Other [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2	0	2	0
Segment Financial Information
Income taxes (benefits)	(10,402)	(10,128)	(21,975)	(17,611)
Consolidated net income	(36,939)	(41,299)	(77,620)	(73,361)
Assets	493,962		493,962		733,366
Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(13)	(40)	(23)	(73)
Segment Financial Information
Income taxes (benefits)	0	0	0	0
Consolidated net income	(31,898)	$ (31,898)	(63,797)	$ (63,797)
Assets	$ (2,437,820)		$ (2,437,820)		$ (2,694,742)

Business Segment Information _2

Business Segment Information Business Segment Information (Restructuring Costs) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Mar. 31, 2019	Dec. 31, 2018	Mar. 31, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Payments for Restructuring	$ 54	$ 0	$ 54	$ 0
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges			56
Payments for Restructuring	54	0	54	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	22	34	56	60
Restructuring Reserve	195	157	195	157	$ 227	$ 193	$ 123	$ 97
Entergy Wholesale Commodities [Member] | Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	22	34	56	60
Restructuring Reserve	181	143	181	143	213	179	109	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	3 Months Ended		6 Months Ended			12 Months Ended
	Jun. 30, 2019USD ($)MMBTUGWh	Jun. 30, 2018USD ($)	Dec. 31, 2019TWh	Jun. 30, 2019USD ($)MMBTUGWh	Jun. 30, 2018USD ($)	Dec. 31, 2018USD ($)counterparty
Risk Management and Fair Values [Abstract]
Cash flow hedges relating to power sales as part of net unrealized gains				$ 67,000,000
Reclassified from accumulated other comprehensive income (OCI) to operating revenues				48,000,000
Maturity of cash flow hedges, Tax	$ 1,000,000	$ 1,000,000		$ 12,000,000	$ (6,000,000)
Maximum length of time over which Company is currently hedging the variability in future cash flows for forecasted power transactions, years				1 year 9 months
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	41,300,000			41,300,000
Total volume of fixed transmission rights outstanding | GWh	110,968			110,968
Change in cash flow hedges due to ineffectiveness		(15,000,000)			(2,000,000)
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset and Liability Unrealized Gains (Loss) Included in Earnings	$ 1,400,000	$ (800,000)		$ (3,500,000)	$ (700,000)
Entergy Arkansas [Member]
Risk Management and Fair Values [Abstract]
Total volume of fixed transmission rights outstanding | GWh	25,480			25,480
Entergy Louisiana [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	34,720,000			34,720,000
Total volume of fixed transmission rights outstanding | GWh	50,209			50,209
Entergy Mississippi [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount	$ 200,000			$ 200,000		$ 200,000
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	6,580,000			6,580,000
Total volume of fixed transmission rights outstanding | GWh	14,072			14,072
Entergy New Orleans [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount	$ 10,200			$ 10,200
Total volume of fixed transmission rights outstanding | GWh	5,160			5,160
Entergy Texas [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount	$ 2,200,000			$ 2,200,000		4,100,000
Total volume of fixed transmission rights outstanding | GWh	15,608			15,608
Gas Hedge Contracts [Member] | Entergy Louisiana [Member]
Risk Management and Fair Values [Abstract]
Maximum Length of Time Hedged in Cash Flow Hedge				4 years 9 months
Gas Hedge Contracts [Member] | Entergy Mississippi [Member]
Risk Management and Fair Values [Abstract]
Maximum Length of Time Hedged in Cash Flow Hedge				9 months
Entergy Wholesale Commodities [Member]
Risk Management and Fair Values [Abstract]
Cash collateral posted	$ 13,000,000			$ 13,000,000		$ 19,000,000
Derivative, Collateral, Obligation to Return Cash	2,000,000			2,000,000
Letters of Credit Held	51,000,000			51,000,000
Number of Derivative Contract Counterparties in a Liability Position | counterparty						6
Dollar amount of hedge contract in a liability position						$ 34,000,000
Utility [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount	$ 2,000,000			$ 2,000,000		$ 4,000,000
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			98.00%
Planned Generation From Non Nuclear Power Plants Sold Forward Under Financial Hedges			72.00%
Total planned generation for remainder of the period | TWh			12.1

Risk Management and Fair Valu_4

Risk Management and Fair Values (Fair Values Of Derivative Instruments) (Details) - USD ($)	Jun. 30, 2019	Dec. 31, 2018
Utility [Member]
Liabilities:
Letters of Credit Outstanding, Amount	$ 2,000,000	$ 4,000,000
Entergy Wholesale Commodities [Member]
Derivatives, Fair Value [Line Items]
Cash collateral posted	13,000,000	19,000,000
Assets:
Derivative, Collateral, Obligation to Return Cash	2,000,000
Liabilities:
Letters of Credit Held	51,000,000
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	2,000,000	20,000,000
Derivative, Collateral, Right to Reclaim Cash	2,000,000	7,000,000
Derivative Liability	0	13,000,000
Other Non-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	2,000,000
Derivative, Collateral, Right to Reclaim Cash	1,000,000
Derivative Liability	1,000,000
Other Non-Current Liabilities [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	1,000,000
Derivative, Collateral, Right to Reclaim Cash	0
Derivative Liability	1,000,000
Other Deferred Debits And Other Assets [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	19,000,000	0
Derivative Asset, Fair Value, Gross Asset	21,000,000	7,000,000
Derivative, Collateral, Obligation to Return Cash	2,000,000	7,000,000
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	0	1,000,000
Derivative Asset, Fair Value, Gross Asset	1,000,000	1,000,000
Derivative, Collateral, Obligation to Return Cash	1,000,000	0
Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1,000,000	2,000,000
Derivative Asset, Fair Value, Gross Asset	1,000,000	2,000,000
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	49,000,000	0
Derivative Asset, Fair Value, Gross Asset	51,000,000	32,000,000
Derivative, Collateral, Obligation to Return Cash	2,000,000	32,000,000
Prepayments And Other [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	5,000,000	2,000,000
Derivative Asset, Fair Value, Gross Asset	8,000,000	4,000,000
Derivative, Collateral, Obligation to Return Cash	3,000,000	2,000,000
Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Utility and Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	29,000,000	15,000,000
Derivative Asset, Fair Value, Gross Asset	31,000,000	16,000,000
Derivative, Collateral, Obligation to Return Cash	2,000,000	1,000,000
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	3,000,000	54,000,000
Derivative, Collateral, Right to Reclaim Cash	3,000,000	33,000,000
Derivative Liability	0	21,000,000
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	3,000,000	1,000,000
Derivative, Collateral, Right to Reclaim Cash	3,000,000	1,000,000
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	5,000,000	1,000,000
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability	5,000,000	1,000,000
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	700,000
Derivative, Collateral, Right to Reclaim Cash	0
Derivative Liability	700,000
Entergy Louisiana [Member] | Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1,400,000	1,600,000
Derivative Asset, Fair Value, Gross Asset	1,400,000	1,600,000
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	100,000	300,000
Derivative Asset, Fair Value, Gross Asset	100,000	300,000
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	15,600,000	8,300,000
Derivative Asset, Fair Value, Gross Asset	15,900,000	8,400,000
Derivative, Collateral, Obligation to Return Cash	(300,000)	(100,000)
Entergy Louisiana [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	1,900,000	1,100,000
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability	1,900,000	1,100,000
Entergy Mississippi [Member]
Liabilities:
Letters of Credit Outstanding, Amount	200,000	200,000
Entergy Mississippi [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	2,800,000	2,200,000
Derivative Asset, Fair Value, Gross Asset	2,800,000	2,200,000
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	3,100,000
Derivative, Collateral, Right to Reclaim Cash	0
Derivative Liability	3,100,000
Entergy New Orleans [Member]
Liabilities:
Letters of Credit Outstanding, Amount	10,200
Entergy New Orleans [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	2,000,000	1,300,000
Derivative Asset, Fair Value, Gross Asset	2,100,000	1,300,000
Derivative, Collateral, Obligation to Return Cash	(100,000)	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		100,000
Derivative, Collateral, Right to Reclaim Cash		0
Derivative Liability		100,000
Entergy Arkansas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	8,200,000	3,400,000
Derivative Asset, Fair Value, Gross Asset	8,300,000	3,600,000
Derivative, Collateral, Obligation to Return Cash	(100,000)	(200,000)
Entergy Texas [Member]
Liabilities:
Letters of Credit Outstanding, Amount	2,200,000	4,100,000
Entergy Texas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	600,000
Derivative Asset, Fair Value, Gross Asset	2,100,000
Derivative, Collateral, Obligation to Return Cash	$ (1,500,000)
Entergy Texas [Member] | Other Current Liabilities [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative, Collateral, Obligation to Return Cash		(1,400,000)
Liabilities:
Derivative Liability, Fair Value, Gross Liability		900,000
Derivative Liability		$ (500,000)

Risk Management and Fair Valu_5

Risk Management and Fair Values (Derivative Instruments Designated as Cash Flow Hedges On Consolidated Statements Of Income) (Details) - Competitive Businesses Operating Revenues [Member] - Electricity Swaps And Options [Member] - Cash Flow Hedging [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 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)	$ 126	$ (80)	$ 152	$ 11
Amount of gain reclassified from accumulated OCI into income (effective portion)	$ 6	$ 3	$ 57	$ (27)

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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 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	(2)	1	3	1
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	(6)	6	(7)	6
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	32	41	53	73
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	3.6	2.1	12	10.1
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	(2.7)	4.9	(1.9)	4.9
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	17.7	25.8	26.5	43.4
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	(3.5)	0.9	(5.2)	0.7
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	2.2	9.8	3.3	17.6
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			0.2	(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	0.7	5.2	2.6	8.4
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	$ 7.8	$ (1.8)	$ 8.1	$ (5.3)

Risk Management and Fair Valu_7

Risk Management and Fair Values (Assets And Liabilities At Fair Value On A Recurring Basis) (Details) - USD ($)		Jun. 30, 2019	Dec. 31, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		$ 574,709,000	$ 424,285,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		39,000,000	51,000,000
Replacement Reserve Escrow		408,000,000	403,000,000
Equity Securities, FV-NI		1,293,000,000	1,686,000,000
Debt Securities		3,413,000,000	2,884,000,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		8,194,000,000	7,818,000,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure		7,000,000	35,000,000
Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		6,000,000	1,000,000
Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		1,000,000	34,000,000
Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities		2,363,000,000	2,350,000,000
Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		73,000,000	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		29,000,000	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		575,000,000	424,000,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		39,000,000	51,000,000
Replacement Reserve Escrow		408,000,000	403,000,000
Equity Securities, FV-NI		1,293,000,000	1,686,000,000
Debt Securities		1,630,000,000	1,259,000,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		3,945,000,000	3,823,000,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure		5,000,000	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		5,000,000	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	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		1,783,000,000	1,625,000,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,784,000,000	1,627,000,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure		1,000,000	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	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		102,000,000	18,000,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure		1,000,000	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		1,000,000	34,000,000
Fair Value, Inputs, Level 3 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		73,000,000	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		29,000,000	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		1,457,000	2,224,000
Replacement Reserve Escrow		81,800,000	80,900,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		85,300,000	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
Entergy New Orleans [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		2,000,000	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		1,500,000	2,200,000
Replacement Reserve Escrow		81,800,000	80,900,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		83,300,000	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
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
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		2,000,000	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
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		2,000,000	1,300,000
Entergy Mississippi [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Temporary Cash Investments Fair Value		123,700,000
Cash Equivalents, at Carrying Value		123,657,000	36,943,000
Assets at fair value on a recurring basis
Replacement Reserve Escrow		32,800,000	32,400,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		159,300,000	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		3,100,000
Entergy Mississippi [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		2,800,000	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]
Temporary Cash Investments Fair Value		123,700,000
Cash Equivalents, at Carrying Value			36,900,000
Assets at fair value on a recurring basis
Replacement Reserve Escrow		32,800,000	32,400,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		156,500,000	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		3,100,000
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]
Temporary Cash Investments Fair Value		0
Cash Equivalents, at Carrying Value			0
Assets at fair value on a recurring basis
Replacement Reserve Escrow		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
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]
Temporary Cash Investments Fair Value		0
Cash Equivalents, at Carrying Value			0
Assets at fair value on a recurring basis
Replacement Reserve Escrow		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		2,800,000	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		2,800,000	2,200,000
Entergy Louisiana [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		44,487,000	43,112,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		3,200,000	3,600,000
Replacement Reserve Escrow		292,900,000	289,500,000
Equity Securities, FV-NI	[1]	8,600,000	13,300,000
Debt Securities	[1]	576,300,000	532,900,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,818,800,000	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		2,600,000	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]	876,200,000	738,800,000
Entergy Louisiana [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,500,000	1,900,000
Entergy Louisiana [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		15,600,000	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		44,500,000	43,100,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		3,200,000	3,600,000
Replacement Reserve Escrow		292,900,000	289,500,000
Equity Securities, FV-NI	[1]	8,600,000	13,300,000
Debt Securities	[1]	191,300,000	162,000,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		540,600,000	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		1,900,000	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]	385,000,000	370,900,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		386,400,000	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		700,000	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		1,400,000	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		15,600,000	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		15,600,000	8,300,000
Entergy Arkansas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		29,148,000	1,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		3,831,000	4,666,000
Equity Securities, FV-NI	[1]	5,100,000	4,000,000
Debt Securities	[1]	401,600,000	381,300,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,072,900,000	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]	625,100,000	526,700,000
Entergy Arkansas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		8,200,000	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		29,100,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		3,800,000	4,700,000
Equity Securities, FV-NI	[1]	5,100,000	4,000,000
Debt Securities	[1]	107,500,000	94,800,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		145,500,000	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]	294,100,000	286,500,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		294,100,000	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		8,200,000	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		8,200,000	3,400,000
Entergy Texas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		31,000	30,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		30,159,000	40,185,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		30,800,000
Entergy Texas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		600,000
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]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		30,200,000	40,200,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		30,200,000
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]
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]
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		600,000
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		600,000
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		82,852,000	95,617,000
Assets at fair value on a recurring basis
Equity Securities, FV-NI	[1]	5,200,000	4,400,000
Debt Securities	[1]	386,600,000	364,200,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,069,700,000	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]	595,000,000	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		82,900,000	95,600,000
Assets at fair value on a recurring basis
Equity Securities, FV-NI	[1]	5,200,000	4,400,000
Debt Securities	[1]	229,900,000	224,500,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		318,000,000	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]	156,700,000	139,700,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		156,700,000	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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Mar. 31, 2019	Dec. 31, 2018	Mar. 31, 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	$ 72		$ 72
Issuance of Financial Transmission Rights	0	$ 0	0	$ 0
Electricity Swaps And Options [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	72		72				$ 75
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value		(25)		(25)	$ (46)	$ (31)		$ (65)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings			3
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings	(2)	(15)		(1)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)	126		152	11
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Other Comprehensive Income (Loss)		(80)
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	(6)	(5)	(52)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements				(30)
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	29	41	29	41	5	15	8	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	21	28	32	48
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(32)	(41)	(53)	(73)
Issuance of Financial Transmission Rights	35	46	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	8.2	10.5	8.2	10.5	1.1	3.4	1.8	3
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				5.8
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	1.1		7.2
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included as Regulatory Liability/Asset		(1)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(3.6)	(2.1)	(12)	(10.1)
Issuance of Financial Transmission Rights	9.6	11.8	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	15.6	18.2	15.6	18.2	2.8	8.3	3.4	10.2
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				31.4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	11.8	20.6	15.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(17.7)	(25.8)	(26.5)	(43.4)
Issuance of Financial Transmission Rights	18.7	20	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	2.8	4.4	2.8	4.4	0.7	2.2	0.9	2.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				15.4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	0.4	8.8
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included as Regulatory Liability/Asset			0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(2.2)	(9.8)	(3.3)	(17.6)
Issuance of Financial Transmission Rights	3.9	4.5	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	2	3	2	3	0.5	1.3	0.7	2.2
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				5.5
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset		3.8	0.6
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included as Regulatory Liability/Asset	(0.5)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(0.7)	(5.2)	(2.6)	(8.4)
Issuance of Financial Transmission Rights	2.7	3.7	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	0.6	4.7	0.6	4.7			$ 1.4	$ 3.4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value					$ (0.3)	$ (0.5)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings				(10.1)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	8.6		9.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included as Regulatory Liability/Asset		(4.6)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(7.8)		(8.1)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements		(1.8)		(5.3)
Issuance of Financial Transmission Rights	$ 0.1	$ 6.1	$ 0.1	$ 6.1

Risk Management and Fair Valu_9

Risk Management and Fair Values (Schedules Of Valuation Techniques) (Details) $ in Millions	Jun. 30, 2019USD ($)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	$ 72
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	$ 7
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	$ 6

Decommissioning Trust Funds (Na

Decommissioning Trust Funds (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018	Jan. 01, 2019	Jan. 01, 2018
Debt Securities, Trading, Measurement Input	$ 499,000		$ 499,000		$ 389,000
Decommissioning Trust Funds [Abstract]
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax						$ (6,806)	$ (632,617)
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts	8,096	$ (2,842)	16,169	$ 2,533
Amortized cost of debt securities	$ 2,849,000		$ 2,849,000		2,511,000
Average coupon rate of debt securities	3.15%		3.15%
Average duration of debt securities, years			5 years 3 months 29 days
Average maturity of debt securities, years			8 years 6 months 3 days
Proceeds from the dispositions of debt securities	$ 361,000	710,000	$ 726,000	1,801,000
Gains from dispositions of debt securities, gross	6,000	1,000	8,000	2,000
Losses from dispositions of debt securities, gross	1,000	15,000	3,000	22,000
Equity Securities, FV-NI, Unrealized Gain	7,000		278,000
Debt Securities [Member]
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts			15,000		(1,000)
Entergy Arkansas [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 393,200		$ 393,200		389,000
Average coupon rate of debt securities	2.75%		2.75%
Average duration of debt securities, years			4 years 9 months 3 days
Average maturity of debt securities, years			7 years 2 months 19 days
Proceeds from the dispositions of debt securities	$ 22,300	86,500	$ 33,200	121,400
Gains from dispositions of debt securities, gross	100	10	100	100
Losses from dispositions of debt securities, gross	18	2,300	100	2,400
Equity Securities, FV-NI, Unrealized Gain	23,000		93,800
Entergy Louisiana [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 550,000		$ 550,000		534,800
Average coupon rate of debt securities	3.87%		3.87%
Average duration of debt securities, years			6 years 5 months 15 days
Average maturity of debt securities, years			12 years 11 months 26 days
Proceeds from the dispositions of debt securities	$ 39,500	43,900	$ 95,700	169,400
Gains from dispositions of debt securities, gross	1,400	10	1,700	500
Losses from dispositions of debt securities, gross	50	400	$ 200	1,200
Percentage Interest in River Bend			30.00%
Equity Securities, FV-NI, Unrealized Gain	32,300		$ 131,100
System Energy [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 372,700		$ 372,700		367,100
Average coupon rate of debt securities	2.98%		2.98%
Average duration of debt securities, years			6 years 6 months 21 days
Average maturity of debt securities, years			9 years 1 month 17 days
Proceeds from the dispositions of debt securities	$ 87,700	145,200	$ 129,800	199,400
Gains from dispositions of debt securities, gross	1,500	200	1,900	300
Losses from dispositions of debt securities, gross	300	$ 3,900	400	$ 4,500
Equity Securities, FV-NI, Unrealized Gain	21,800		89,200
Indian Point 3 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	876,000		876,000		781,000
Indian Point 1 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	525,000		525,000		471,000
Indian Point 2 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	664,000		664,000		598,000
Palisades [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	489,000		489,000		444,000
Pilgrim [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	$ 1,035,000		$ 1,035,000		1,028,000
Vermont Yankee [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value					$ 532,000

Decommissioning Trust Funds (Se

Decommissioning Trust Funds (Securities Held) (Details) - Debt Securities [Member] - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Fair Value	$ 2,914	$ 2,495
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	92	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	401.6	381.3
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	8.8	0.6
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.5	8.2
Entergy Louisiana [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	576.3	532.9
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	26.6	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	386.6	364.2
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	14.1	2.9
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	$ 0.2	$ 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	Jun. 30, 2019	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	$ 163	$ 652
More than 12 months Fair Value	180	782
Total Fair Value	343	1,434
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0	9
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	2	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	0.5	65.8
More than 12 months Fair Value	52.7	231.1
Total Fair Value	53.2	296.9
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0	0.5
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.5	7.7
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	0.5	8.2
Entergy Louisiana [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	5	170.1
More than 12 months Fair Value	31.7	145.8
Total Fair Value	36.7	315.9
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0	2.1
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.3	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	42.6	89.7
More than 12 months Fair Value	14.1	79.8
Total Fair Value	56.7	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	0.1	3.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	$ 0.2	$ 5.8

Decommissioning Trust Funds (Fa

Decommissioning Trust Funds (Fair Value Of Debt Securities By Contractual Maturities) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Fair value of debt securities by contractual maturities
Less than 1 year	$ 226	$ 199
1 year - 5 years	1,342	1,066
5 years - 10 years	654	544
10 years - 15 years	64	77
15 years - 20 years	91	78
20 years+	537	531
Total	2,914	2,495
Entergy Arkansas [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	59.5	32.5
1 year - 5 years	143.2	170.3
5 years - 10 years	129	114
10 years - 15 years	11.1	10.3
15 years - 20 years	9.7	8.1
20 years+	49.1	46.1
Total	401.6	381.3
Entergy Louisiana [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	52.5	31.1
1 year - 5 years	128.7	130.5
5 years - 10 years	134.4	111
10 years - 15 years	27.6	29
15 years - 20 years	44.3	37.1
20 years+	188.8	194.2
Total	576.3	532.9
System Energy [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	11.3	22.8
1 year - 5 years	197.6	188
5 years - 10 years	90.5	73.4
10 years - 15 years	1.7	5.2
15 years - 20 years	3.2	10.2
20 years+	82.3	64.6
Total	$ 386.6	$ 364.2

Income Taxes Income Taxes (Narr

Income Taxes Income Taxes (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended	12 Months Ended
	Mar. 31, 2019	Jun. 30, 2019	Dec. 31, 2022	Dec. 31, 2021
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
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%

Income Taxes Income Taxes (Redu

Income Taxes Income Taxes (Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Entergy Arkansas [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	$ 25	$ 108	$ 57	$ 108
Entergy Louisiana [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	7	31	14	31
Entergy Mississippi [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	0	129	0	129
Entergy New Orleans [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	2	0	2	0
Entergy Texas [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	20	0	42	0
System Energy [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	$ 7	$ 11	$ 7	$ 11

Property, Plant, And Equipment

Property, Plant, And Equipment (Narrative) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Construction expenditures in accounts payable	$ 292	$ 311
Entergy Arkansas [Member]
Construction expenditures in accounts payable	37.9	35.7
Entergy Louisiana [Member]
Construction expenditures in accounts payable	71.3	104.6
Entergy Mississippi [Member]
Construction expenditures in accounts payable	10.8	13.6
Entergy New Orleans [Member]
Construction expenditures in accounts payable	9.9	5.8
Entergy Texas [Member]
Construction expenditures in accounts payable	52.4	55.6
System Energy [Member]
Construction expenditures in accounts payable	$ 19.7	$ 26.3

Variable Interest Entities (Nar

Variable Interest Entities (Narrative) (Details) - Grand Gulf [Member] - System Energy [Member] - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jun. 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	$ 8.6

Revenue Recognition (Disaggrega

Revenue Recognition (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,666,209	$ 2,668,770	$ 5,275,792	$ 5,392,650
Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,345,727	2,330,225	4,466,751	4,578,486
Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	30,699	29,943	85,647	86,638
Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	289,783	308,602	723,394	727,526
Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	770,373	768,710	1,572,911	1,660,795
Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	595,025	581,899	1,149,082	1,177,620
Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	641,733	624,818	1,242,734	1,222,004
Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	57,623	56,823	110,584	113,301
Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	75,318	69,212	159,753	138,738
Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	195,952	219,391	211,422	246,822
Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	9,703	9,372	20,265	19,206
Non-Customer [Member] | Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	9,385	(22,960)	82,525	(13,171)
Competitive Business Sales [Member] | Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	280,398	331,562	640,869	740,697
Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,064,754	2,032,250	4,075,311	4,173,720
Entergy Arkansas [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	542,929	494,605	1,088,741	1,045,629
Entergy Arkansas [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	542,929	494,605	1,088,741	1,045,629
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	157,714	159,130	367,581	394,654
Entergy Arkansas [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	125,555	93,741	250,133	214,375
Entergy Arkansas [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	118,913	97,973	240,491	209,450
Entergy Arkansas [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	4,971	3,766	9,869	8,414
Entergy Arkansas [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	74,501	53,195	154,085	119,299
Entergy Arkansas [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	58,209	84,102	60,514	94,125
Entergy Arkansas [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	3,066	2,698	6,068	5,312
Entergy Arkansas [Member] | Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	407,153	354,610	868,074	826,893
Entergy Louisiana [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,106,317	1,072,788	2,065,647	2,102,132
Entergy Louisiana [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,094,259	1,061,689	2,030,952	2,066,795
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	12,058	11,099	34,695	35,337
Entergy Louisiana [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	290,366	267,915	554,431	563,433
Entergy Louisiana [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	232,134	221,740	438,912	446,667
Entergy Louisiana [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	384,919	368,678	731,598	721,014
Entergy Louisiana [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	17,925	16,705	34,817	34,015
Entergy Louisiana [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	83,208	111,801	167,164	201,056
Entergy Louisiana [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	80,307	70,027	92,746	90,529
Entergy Louisiana [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	5,400	4,823	11,284	10,081
Entergy Louisiana [Member] | Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	925,344	875,038	1,759,758	1,765,129
Entergy Mississippi [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	302,737	353,689	584,981	669,432
Entergy Mississippi [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	302,737	353,689	584,981	669,432
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	116,801	132,730	245,610	281,073
Entergy Mississippi [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	102,275	117,351	200,189	227,811
Entergy Mississippi [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	38,739	46,129	76,436	88,629
Entergy Mississippi [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	10,521	11,452	20,557	22,300
Entergy Mississippi [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	4,994	11,776	9,808	13,769
Entergy Mississippi [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	26,982	31,696	27,387	30,977
Entergy Mississippi [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,425	2,555	4,994	4,873
Entergy Mississippi [Member] | Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	268,336	307,662	542,792	619,813
Entergy New Orleans [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	175,793	178,446	338,987	366,721
Entergy New Orleans [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	157,152	159,602	288,035	315,420
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	18,641	18,844	50,952	51,301
Entergy New Orleans [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	58,621	58,232	110,697	122,807
Entergy New Orleans [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	53,981	54,524	99,723	108,796
Entergy New Orleans [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	8,490	9,267	15,740	16,838
Entergy New Orleans [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	18,984	18,448	34,886	36,139
Entergy New Orleans [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	8,579	6,190	18,803	19,527
Entergy New Orleans [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	7,263	11,623	5,556	8,511
Entergy New Orleans [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,234	1,318	2,630	2,802
Entergy New Orleans [Member] | Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	140,076	140,471	261,046	284,580
Entergy Texas [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	363,580	403,486	704,054	752,426
Entergy Texas [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	363,580	403,486	704,054	752,426
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	146,871	150,703	294,592	298,828
Entergy Texas [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	81,080	94,544	160,125	179,971
Entergy Texas [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	90,672	102,771	178,470	186,073
Entergy Texas [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	5,222	6,452	10,455	12,433
Entergy Texas [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	14,772	25,177	31,548	48,538
Entergy Texas [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	24,656	23,468	28,153	25,733
Entergy Texas [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	307	371	711	850
Entergy Texas [Member] | Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	323,845	354,470	643,642	677,305
System Energy [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 139,009	$ 112,456	$ 279,113	$ 260,899

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	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jun. 30, 2019	Jan. 31, 2019	Dec. 31, 2015	Dec. 31, 1989	Dec. 31, 1988
Operating Lease, Right-of-Use Asset					$ 234,000,000
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
Entergy Arkansas [Member]
Operating Lease, Right-of-Use Asset					48,567,000
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					11,167,000
Entergy Louisiana [Member]
Operating Lease, Right-of-Use Asset					33,054,000
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					16,846,000
Entergy Mississippi [Member]
Operating Lease, Right-of-Use Asset					18,791,000
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					6,671,000
Entergy New Orleans [Member]
Operating Lease, Right-of-Use Asset					4,172,000
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					2,991,000
Entergy Texas [Member]
Operating Lease, Right-of-Use Asset					12,540,000
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					$ 5,439,000
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	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019
Operating Lease, Expense	$ 15,255	$ 30,976
Finance Lease, Right-of-Use Asset, Amortization	4,980	7,892
Finance Lease, Interest Expense	1,081	1,834
Entergy Arkansas [Member]
Operating Lease, Expense	3,124	6,419
Finance Lease, Right-of-Use Asset, Amortization	1,198	1,828
Finance Lease, Interest Expense	198	303
Entergy Louisiana [Member]
Operating Lease, Expense	2,824	5,850
Finance Lease, Right-of-Use Asset, Amortization	1,975	3,000
Finance Lease, Interest Expense	299	451
Entergy Mississippi [Member]
Operating Lease, Expense	1,716	3,468
Finance Lease, Right-of-Use Asset, Amortization	691	1,039
Finance Lease, Interest Expense	117	176
Entergy New Orleans [Member]
Operating Lease, Expense	351	709
Finance Lease, Right-of-Use Asset, Amortization	342	518
Finance Lease, Interest Expense	55	85
Entergy Texas [Member]
Operating Lease, Expense	977	2,062
Finance Lease, Right-of-Use Asset, Amortization	325	630
Finance Lease, Interest Expense	$ 53	$ 99

Leases Leases (Lease, Assets) (

Leases Leases (Lease, Assets) (Details) $ in Thousands	Jun. 30, 2019USD ($)
Operating Lease, Right-of-Use Asset	$ 234,000
Finance Lease, Right-of-Use Asset	60,000
Entergy Arkansas [Member]
Operating Lease, Right-of-Use Asset	48,567
Finance Lease, Right-of-Use Asset	11,167
Entergy Louisiana [Member]
Operating Lease, Right-of-Use Asset	33,054
Finance Lease, Right-of-Use Asset	16,846
Entergy Mississippi [Member]
Operating Lease, Right-of-Use Asset	18,791
Finance Lease, Right-of-Use Asset	6,671
Entergy New Orleans [Member]
Operating Lease, Right-of-Use Asset	4,172
Finance Lease, Right-of-Use Asset	2,991
Entergy Texas [Member]
Operating Lease, Right-of-Use Asset	12,540
Finance Lease, Right-of-Use Asset	$ 5,439

Leases Leases (Lease, Liabiliti

Leases Leases (Lease, Liabilities) (Details) $ in Thousands	Jun. 30, 2019USD ($)
Operating Lease, Liability, Current	$ 51,885
Finance Lease, Liability, Current	11,177
Operating Lease, Liability, Noncurrent	182,236
Finance Lease, Liability, Noncurrent	53,375
Entergy Arkansas [Member]
Operating Lease, Liability, Current	10,374
Finance Lease, Liability, Current	2,408
Operating Lease, Liability, Noncurrent	38,195
Finance Lease, Liability, Noncurrent	8,756
Entergy Louisiana [Member]
Operating Lease, Liability, Current	9,727
Finance Lease, Liability, Current	3,840
Operating Lease, Liability, Noncurrent	23,333
Finance Lease, Liability, Noncurrent	13,000
Entergy Mississippi [Member]
Operating Lease, Liability, Current	6,180
Finance Lease, Liability, Current	1,402
Operating Lease, Liability, Noncurrent	12,812
Finance Lease, Liability, Noncurrent	5,269
Entergy New Orleans [Member]
Operating Lease, Liability, Current	1,218
Finance Lease, Liability, Current	662
Operating Lease, Liability, Noncurrent	2,953
Finance Lease, Liability, Noncurrent	2,329
Entergy Texas [Member]
Operating Lease, Liability, Current	3,251
Finance Lease, Liability, Current	1,240
Operating Lease, Liability, Noncurrent	9,375
Finance Lease, Liability, Noncurrent	$ 4,112

Leases Leases (Lease, Terms and

Leases Leases (Lease, Terms and Discount Rate) (Details)	Jun. 30, 2019
Operating Lease, Weighted Average Remaining Lease Term	5 years 5 months 1 day
Finance Lease, Weighted Average Remaining Lease Term	6 years 11 months 8 days
Operating Lease, Weighted Average Discount Rate, Percent	3.93%
Finance Lease, Weighted Average Discount Rate, Percent	4.71%
Entergy Arkansas [Member]
Operating Lease, Weighted Average Remaining Lease Term	6 years 2 months 19 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 6 months 18 days
Operating Lease, Weighted Average Discount Rate, Percent	3.79%
Finance Lease, Weighted Average Discount Rate, Percent	3.78%
Entergy Louisiana [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 3 months 7 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 3 months 7 days
Operating Lease, Weighted Average Discount Rate, Percent	3.80%
Finance Lease, Weighted Average Discount Rate, Percent	3.78%
Entergy Mississippi [Member]
Operating Lease, Weighted Average Remaining Lease Term	5 years 1 month 9 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 5 months 1 day
Operating Lease, Weighted Average Discount Rate, Percent	3.80%
Finance Lease, Weighted Average Discount Rate, Percent	3.77%
Entergy New Orleans [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 14 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 9 months 18 days
Operating Lease, Weighted Average Discount Rate, Percent	3.96%
Finance Lease, Weighted Average Discount Rate, Percent	3.95%
Entergy Texas [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 6 months 7 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 2 months 23 days
Operating Lease, Weighted Average Discount Rate, Percent	3.93%
Finance Lease, Weighted Average Discount Rate, Percent	3.89%

Leases Leases (Lease, Maturity)

Leases Leases (Lease, Maturity) (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Dec. 31, 2018
Operating Lease, Weighted Average Remaining Lease Term	5 years 5 months 1 day
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 30,913
Finance Lease, Liability, Payments, Remainder of Fiscal Year	7,067
Lessee, Operating Lease, Liability, Payments, Due Year Two	57,615	$ 31,876
Finance Lease, Liability, Payments, Due Year Two	13,052
Lessee, Operating Lease, Liability, Payments, Due Year Three	49,126	32,609
Finance Lease, Liability, Payments, Due Year Three	11,505
Lessee, Operating Lease, Liability, Payments, Due Year Four	40,519	10,180
Finance Lease, Liability, Payments, Due Year Four	10,307
Lessee, Operating Lease, Liability, Payments, Due Year Five	32,907
Finance Lease, Liability, Payments, Due Year Five	9,231
Lessee, Operating Lease, Liability, Payments, Due after Year Five	53,491
Finance Lease, Liability, Payments, Due after Year Five	25,696
Lessee, Operating Lease, Liability, Payments, Due	264,571	105,824
Operating Lease, Cost	30,450
Finance Lease, Liability, Payments, Due	76,858
Finance Lease, Interest Payment on Liability	12,306
Present Value Net Minimum Operating Lease Payments	234,121
Present Value Net Minimum Financing Lease Payments	$ 64,552
Finance Lease, Weighted Average Remaining Lease Term	6 years 11 months 8 days
Operating Lease, Weighted Average Discount Rate, Percent	3.93%
Finance Lease, Weighted Average Discount Rate, Percent	4.71%
Entergy Arkansas [Member]
Operating Lease, Weighted Average Remaining Lease Term	6 years 2 months 19 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 6,070
Finance Lease, Liability, Payments, Remainder of Fiscal Year	1,398
Lessee, Operating Lease, Liability, Payments, Due Year Two	11,014
Finance Lease, Liability, Payments, Due Year Two	2,560
Lessee, Operating Lease, Liability, Payments, Due Year Three	9,117
Finance Lease, Liability, Payments, Due Year Three	2,164
Lessee, Operating Lease, Liability, Payments, Due Year Four	6,782
Finance Lease, Liability, Payments, Due Year Four	1,875
Lessee, Operating Lease, Liability, Payments, Due Year Five	5,619
Finance Lease, Liability, Payments, Due Year Five	1,648
Lessee, Operating Lease, Liability, Payments, Due after Year Five	15,771
Finance Lease, Liability, Payments, Due after Year Five	2,698
Lessee, Operating Lease, Liability, Payments, Due	54,373
Operating Lease, Cost	5,804
Finance Lease, Liability, Payments, Due	12,343
Finance Lease, Interest Payment on Liability	1,179
Present Value Net Minimum Operating Lease Payments	48,569
Present Value Net Minimum Financing Lease Payments	$ 11,164
Finance Lease, Weighted Average Remaining Lease Term	5 years 6 months 18 days
Operating Lease, Weighted Average Discount Rate, Percent	3.79%
Finance Lease, Weighted Average Discount Rate, Percent	3.78%
Entergy Louisiana [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 3 months 7 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 5,419
Finance Lease, Liability, Payments, Remainder of Fiscal Year	2,235
Lessee, Operating Lease, Liability, Payments, Due Year Two	9,797
Finance Lease, Liability, Payments, Due Year Two	4,032
Lessee, Operating Lease, Liability, Payments, Due Year Three	8,046
Finance Lease, Liability, Payments, Due Year Three	3,377
Lessee, Operating Lease, Liability, Payments, Due Year Four	5,267
Finance Lease, Liability, Payments, Due Year Four	2,937
Lessee, Operating Lease, Liability, Payments, Due Year Five	3,391
Finance Lease, Liability, Payments, Due Year Five	2,489
Lessee, Operating Lease, Liability, Payments, Due after Year Five	3,777
Finance Lease, Liability, Payments, Due after Year Five	3,453
Lessee, Operating Lease, Liability, Payments, Due	35,697
Operating Lease, Cost	2,637
Finance Lease, Liability, Payments, Due	18,523
Finance Lease, Interest Payment on Liability	1,683
Present Value Net Minimum Operating Lease Payments	33,060
Present Value Net Minimum Financing Lease Payments	$ 16,840
Finance Lease, Weighted Average Remaining Lease Term	5 years 3 months 7 days
Operating Lease, Weighted Average Discount Rate, Percent	3.80%
Finance Lease, Weighted Average Discount Rate, Percent	3.78%
Entergy Mississippi [Member]
Operating Lease, Weighted Average Remaining Lease Term	5 years 1 month 9 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 3,580
Finance Lease, Liability, Payments, Remainder of Fiscal Year	813
Lessee, Operating Lease, Liability, Payments, Due Year Two	5,888
Finance Lease, Liability, Payments, Due Year Two	1,549
Lessee, Operating Lease, Liability, Payments, Due Year Three	4,759
Finance Lease, Liability, Payments, Due Year Three	1,384
Lessee, Operating Lease, Liability, Payments, Due Year Four	3,338
Finance Lease, Liability, Payments, Due Year Four	1,191
Lessee, Operating Lease, Liability, Payments, Due Year Five	1,237
Finance Lease, Liability, Payments, Due Year Five	977
Lessee, Operating Lease, Liability, Payments, Due after Year Five	2,340
Finance Lease, Liability, Payments, Due after Year Five	1,444
Lessee, Operating Lease, Liability, Payments, Due	21,142
Operating Lease, Cost	2,150
Finance Lease, Liability, Payments, Due	7,358
Finance Lease, Interest Payment on Liability	687
Present Value Net Minimum Operating Lease Payments	18,992
Present Value Net Minimum Financing Lease Payments	$ 6,671
Finance Lease, Weighted Average Remaining Lease Term	5 years 5 months 1 day
Operating Lease, Weighted Average Discount Rate, Percent	3.80%
Finance Lease, Weighted Average Discount Rate, Percent	3.77%
Entergy New Orleans [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 14 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 680
Finance Lease, Liability, Payments, Remainder of Fiscal Year	403
Lessee, Operating Lease, Liability, Payments, Due Year Two	1,225
Finance Lease, Liability, Payments, Due Year Two	645
Lessee, Operating Lease, Liability, Payments, Due Year Three	954
Finance Lease, Liability, Payments, Due Year Three	535
Lessee, Operating Lease, Liability, Payments, Due Year Four	632
Finance Lease, Liability, Payments, Due Year Four	484
Lessee, Operating Lease, Liability, Payments, Due Year Five	470
Finance Lease, Liability, Payments, Due Year Five	437
Lessee, Operating Lease, Liability, Payments, Due after Year Five	693
Finance Lease, Liability, Payments, Due after Year Five	834
Lessee, Operating Lease, Liability, Payments, Due	4,654
Operating Lease, Cost	483
Finance Lease, Liability, Payments, Due	3,338
Finance Lease, Interest Payment on Liability	347
Present Value Net Minimum Operating Lease Payments	4,171
Present Value Net Minimum Financing Lease Payments	$ 2,991
Finance Lease, Weighted Average Remaining Lease Term	5 years 9 months 18 days
Operating Lease, Weighted Average Discount Rate, Percent	3.96%
Finance Lease, Weighted Average Discount Rate, Percent	3.95%
Entergy Texas [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 6 months 7 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 1,924
Finance Lease, Liability, Payments, Remainder of Fiscal Year	727
Lessee, Operating Lease, Liability, Payments, Due Year Two	3,776	31,876
Finance Lease, Liability, Payments, Due Year Two	1,297
Lessee, Operating Lease, Liability, Payments, Due Year Three	3,026	32,609
Finance Lease, Liability, Payments, Due Year Three	1,104
Lessee, Operating Lease, Liability, Payments, Due Year Four	2,061	10,180
Finance Lease, Liability, Payments, Due Year Four	897
Lessee, Operating Lease, Liability, Payments, Due Year Five	1,704
Finance Lease, Liability, Payments, Due Year Five	759
Lessee, Operating Lease, Liability, Payments, Due after Year Five	1,862
Finance Lease, Liability, Payments, Due after Year Five	1,111
Lessee, Operating Lease, Liability, Payments, Due	14,353	$ 105,824
Operating Lease, Cost	1,726
Finance Lease, Liability, Payments, Due	5,895
Finance Lease, Interest Payment on Liability	543
Present Value Net Minimum Operating Lease Payments	12,627
Present Value Net Minimum Financing Lease Payments	$ 5,352
Finance Lease, Weighted Average Remaining Lease Term	5 years 2 months 23 days
Operating Lease, Weighted Average Discount Rate, Percent	3.93%
Finance Lease, Weighted Average Discount Rate, Percent	3.89%

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	Jun. 30, 2019	Dec. 31, 2018
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months		$ 31,159
Lessee, Operating Lease, Liability, Payments, Due Year Two	$ 57,615	31,876
Lessee, Operating Lease, Liability, Payments, Due Year Three	49,126	32,609
Lessee, Operating Lease, Liability, Payments, Due Year Four	40,519	10,180
Lessee, Operating Lease, Liability, Payments, Due	264,571	105,824
Entergy Texas [Member]
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months		31,159
Lessee, Operating Lease, Liability, Payments, Due Year Two	3,776	31,876
Lessee, Operating Lease, Liability, Payments, Due Year Three	3,026	32,609
Lessee, Operating Lease, Liability, Payments, Due Year Four	2,061	10,180
Lessee, Operating Lease, Liability, Payments, Due	14,353	$ 105,824
Entergy Louisiana [Member]
Lessee, Operating Lease, Liability, Payments, Due Year Two	9,797
Lessee, Operating Lease, Liability, Payments, Due Year Three	8,046
Lessee, Operating Lease, Liability, Payments, Due Year Four	5,267
Lessee, Operating Lease, Liability, Payments, Due	$ 35,697

Leases Leases (Present Value Of

Leases Leases (Present Value Of future Minimum Lease Payments Sale Leaseback Transactions) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Long-term Debt, Fair Value	$ 18,126,143		$ 18,126,143		$ 15,880,239
Interest Expense, Debt	201,112	$ 192,314	402,105	$ 375,237
Entergy Arkansas [Member]
Long-term Debt, Fair Value	3,523,519		3,523,519		3,002,627
Interest Expense, Debt	35,827	30,917	69,210	60,683
Entergy Louisiana [Member]
Long-term Debt, Fair Value	7,892,133		7,892,133		6,834,134
Interest Expense, Debt	77,631	73,582	152,334	143,678
Entergy Mississippi [Member]
Long-term Debt, Fair Value	1,680,869		1,680,869		1,276,452
Interest Expense, Debt	15,342	14,061	29,882	27,966
Entergy New Orleans [Member]
Long-term Debt, Fair Value	511,691		511,691		491,569
Interest Expense, Debt	6,019	5,269	11,955	10,548
Entergy Texas [Member]
Long-term Debt, Fair Value	1,786,350		1,786,350		1,528,828
Interest Expense, Debt	20,153	21,835	42,613	43,886
System Energy [Member]
Long-term Debt, Fair Value	571,693		571,693		596,123
Interest Expense, Debt	$ 8,524	$ 9,656	$ 17,921	$ 18,981
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 ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Jun. 30, 2019	Jan. 31, 2019
Business Acquisition [Line Items]
Amount Drawn/ Outstanding		$ 150
Discontinued Operation, Tax Effect of Discontinued Operation	$ 29
Restructuring Costs and Asset Impairment Charges	5.4
After-Tax Asset Impairment Charge	$ 4.2
Entergy Nuclear Vermont Yankee [Member]
Business Acquisition [Line Items]
Percentage of Undivided Ownership Interest			100.00%
Amount Drawn/ Outstanding		$ 139	$ 139

Uncategorized Items - etr-06x30

Label	Element	Value
Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	$ 7,936,155,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	8,844,305,000
Treasury Stock [Member]
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
Treasury Stock [Member] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	(5,397,637,000)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	(5,273,719,000)
AOCI Attributable to Parent [Member] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	(563,979,000)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	(656,148,000)
Common Stock [Member]
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
Common Stock [Member] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	2,548,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	2,616,000
Retained Earnings [Member]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	6,806,000
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	576,257,000
Retained Earnings [Member] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	8,553,959,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	8,727,956,000
Additional Paid-in Capital [Member]
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] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	5,433,433,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	5,951,431,000
Subsidiaries Preferred Stock [Member]
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] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	$ 0