Entergy (ETR) 10-Q 6 Nov 18 2018 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2018	Oct. 31, 2018
Entity Registrant Name	ENTERGY CORP /DE/
Entity Central Index Key	65,984
Document Type	10-Q
Document Period End Date	Sep. 30, 2018
Amendment Flag	false
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		181,142,215
Entity Emerging Growth Company	false
Entity Small Business	false
Entergy Arkansas [Member]
Entity Registrant Name	ENTERGY ARKANSAS, INC.
Entity Central Index Key	7,323
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entergy Louisiana [Member]
Entity Registrant Name	ENTERGY LOUISIANA, LLC
Entity Central Index Key	1,348,952
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entergy Mississippi [Member]
Entity Registrant Name	ENTERGY MISSISSIPPI, INC.
Entity Central Index Key	66,901
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entergy New Orleans [Member]
Entity Registrant Name	ENTERGY NEW ORLEANS, LLC
Entity Central Index Key	71,508
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entergy Texas [Member]
Entity Registrant Name	ENTERGY TEXAS, INC.
Entity Central Index Key	1,427,437
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
System Energy [Member]
Entity Registrant Name	SYSTEM ENERGY RESOURCES, INC.
Entity Central Index Key	202,584
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer

Consolidated Statements Of Inco

Consolidated Statements Of Income - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 3,104,319	$ 3,243,628	$ 8,496,970	$ 8,450,636
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	729,269	612,950	1,638,367	1,426,462
Nuclear refueling outage expenses	37,937	43,273	116,057	124,126
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	854,013	775,001	2,477,699	2,416,825
Asset Impairment Charges	155,215	16,221	297,082	421,584
Asset Write-Offs, Impairments, And Related Charges	155,000	16,000	297,000	422,000
Decommissioning	93,829	95,392	285,834	310,062
Taxes, Other	161,916	159,474	485,682	469,090
Other Depreciation and Amortization	324,628	354,739	1,022,099	1,052,332
Other regulatory charges (credits) - net	37,097	19,435	223,416	(59,314)
Costs and Expenses	2,833,284	2,484,625	7,798,673	7,343,571
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property	0	0	0	(16,270)
OPERATING INCOME	271,035	759,003	698,297	1,123,335
OTHER INCOME
Allowance for equity funds used during construction	32,354	24,338	92,367	65,722
Investment Income, Net	177,081	58,332	265,086	194,978
Miscellaneous - net	(43,591)	(31,335)	(123,439)	(78,726)
TOTAL	165,844	51,335	234,014	181,974
INTEREST EXPENSE
Interest expense	195,311	178,391	570,548	522,857
Allowance for borrowed funds used during construction	(15,244)	(11,492)	(43,177)	(31,057)
TOTAL	180,067	166,899	527,371	491,800
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	256,812	643,439	404,940	813,509
Income taxes	(283,006)	241,795	(519,937)	(87,555)
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	3,439	3,446	10,317	10,338
Net Income (Loss) Available to Common Stockholders, Basic	$ 536,379	$ 398,198	$ 914,560	$ 890,726
Earnings per average common share:
Basic (in dollars per share)	$ 2.96	$ 2.22	$ 5.06	$ 4.96
Diluted (in dollars per share)	2.92	2.21	5.01	4.94
Dividends declared per common share (in dollars per share)	$ 0.89	$ 0.87	$ 2.67	$ 2.61
Basic average number of common shares outstanding (in shares)	181,002,303	179,563,819	180,845,440	179,458,914
Diluted average number of common shares outstanding (in shares)	183,664,583	180,464,069	182,692,325	180,163,074
Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,697,887	$ 2,793,798	$ 7,276,374	$ 7,056,758
Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	26,352	26,585	112,990	100,011
Competitive Businesses [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	380,080	423,245	1,107,606	1,293,867
Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	439,380	408,140	1,252,437	1,182,404
Entergy Arkansas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	568,399		1,614,028
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	164,438	133,254	379,240	283,354
Nuclear refueling outage expenses	19,062	22,988	61,623	59,942
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	188,882	171,498	536,032	502,696
Decommissioning	15,226	14,320	44,971	42,321
Taxes, Other	27,972	29,259	80,322	78,438
Other Depreciation and Amortization	73,579	70,433	218,261	206,586
Other regulatory charges (credits) - net	(13,758)	(5,219)	(29,378)	(10,797)
Costs and Expenses	533,614	499,956	1,486,095	1,355,648
OPERATING INCOME	34,785	173,270	127,933	288,591
OTHER INCOME
Allowance for equity funds used during construction	3,735	4,140	12,214	13,922
Investment Income, Net	12,060	6,738	21,352	27,865
Miscellaneous - net	(3,063)	(3,332)	(10,815)	(9,976)
TOTAL	12,732	7,546	22,751	31,811
INTEREST EXPENSE
Interest expense	31,632	31,010	92,315	86,776
Allowance for borrowed funds used during construction	(1,739)	(1,944)	(5,737)	(6,458)
TOTAL	29,893	29,066	86,578	80,318
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	17,624	151,750	64,106	240,084
Income taxes	(111,266)	59,112	(183,595)	94,592
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	357	357	1,071	1,071
Net Income (Loss) Available to Common Stockholders, Basic	128,533	92,281	246,630	144,421
Entergy Arkansas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	568,399	673,226	1,614,028	1,644,239
Entergy Arkansas [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	0		0
Entergy Arkansas [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	58,213	63,423	195,024	193,108
Entergy Louisiana [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,206,612	1,290,494	3,308,744	3,254,711
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	318,987	301,584	700,296	635,684
Nuclear refueling outage expenses	12,969	13,616	38,739	38,565
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	239,230	229,664	724,604	683,754
Decommissioning	13,654	12,444	39,906	36,850
Taxes, Other	44,594	45,059	143,021	135,418
Other Depreciation and Amortization	124,030	117,923	366,950	349,660
Other regulatory charges (credits) - net	(1,433)	(1,795)	30,781	(78,503)
Costs and Expenses	970,094	991,820	2,780,746	2,597,253
OPERATING INCOME	236,518	298,674	527,998	657,458
OTHER INCOME
Allowance for equity funds used during construction	20,423	13,393	57,292	34,492
Investment Income, Net	53,009	42,662	143,137	124,411
Miscellaneous - net	(25,782)	(11,542)	(56,217)	(29,573)
TOTAL	47,650	44,513	144,212	129,330
INTEREST EXPENSE
Interest expense	73,084	69,518	216,762	205,316
Allowance for borrowed funds used during construction	(10,168)	(6,713)	(28,382)	(17,428)
TOTAL	62,916	62,805	188,380	187,888
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	221,252	280,382	483,830	598,900
Income taxes	2,944	94,098	(30,430)	193,759
Net Income (Loss) Available to Common Stockholders, Basic	218,308	186,284	514,260	405,141
Entergy Louisiana [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,196,278	1,280,475	3,263,073	3,216,677
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	10,334	10,019	45,671	38,034
Entergy Louisiana [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	218,063	273,325	736,449	795,825
Entergy Mississippi [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	367,734		1,037,166
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	78,533	61,681	207,724	146,869
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	69,936	56,713	193,979	170,337
Taxes, Other	26,024	23,568	75,212	71,518
Other Depreciation and Amortization	37,752	36,176	114,293	106,935
Other regulatory charges (credits) - net	5,487	(3,840)	133,715	(13,983)
Costs and Expenses	322,519	264,384	1,014,320	718,085
OPERATING INCOME	45,215	84,813	22,846	180,767
OTHER INCOME
Allowance for equity funds used during construction	2,251	2,566	6,351	6,741
Investment Income, Net	1	0	26	33
Miscellaneous - net	116	(832)	(1,866)	(2,894)
TOTAL	2,368	1,734	4,511	3,880
INTEREST EXPENSE
Interest expense	13,950	12,713	41,916	37,953
Allowance for borrowed funds used during construction	(944)	(1,048)	(2,662)	(2,681)
TOTAL	13,006	11,665	39,254	35,272
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	34,577	74,882	(11,897)	149,375
Income taxes	(16,156)	28,337	(123,715)	57,369
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	238	238	715	715
Net Income (Loss) Available to Common Stockholders, Basic	50,495	46,307	111,103	91,291
Entergy Mississippi [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	367,734	349,197	1,037,166	898,852
Entergy Mississippi [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	0		0
Entergy Mississippi [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	104,787	90,086	289,397	236,409
Entergy New Orleans [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	200,182	199,017	566,903	544,228
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	54,754	26,082	93,859	79,118
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	30,593	26,092	87,312	73,462
Taxes, Other	15,551	15,135	43,534	41,397
Other Depreciation and Amortization	14,059	13,286	41,756	39,356
Other regulatory charges (credits) - net	5,853	5,514	18,313	6,717
Costs and Expenses	178,638	165,246	499,547	460,651
OPERATING INCOME	21,544	33,771	67,356	83,577
OTHER INCOME
Allowance for equity funds used during construction	1,694	654	3,762	1,656
Investment Income, Net	30	222	330	521
Miscellaneous - net	(660)	(317)	(2,401)	(617)
TOTAL	1,064	559	1,691	1,560
INTEREST EXPENSE
Interest expense	5,388	5,313	15,936	16,012
Allowance for borrowed funds used during construction	(626)	(229)	(1,390)	(580)
TOTAL	4,762	5,084	14,546	15,432
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	17,846	29,246	54,501	69,705
Income taxes	(3,561)	10,717	3,943	25,316
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	0	241	0	724
Net Income (Loss) Available to Common Stockholders, Basic	21,407	18,288	50,558	43,665
Entergy New Orleans [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	184,164	182,451	499,584	482,251
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	16,018	16,566	67,319	61,977
Entergy New Orleans [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	57,828	79,137	214,773	220,601
Entergy Texas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	477,231		1,229,657
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	79,130	60,292	154,925	164,447
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	58,795	51,874	171,317	162,594
Taxes, Other	20,752	20,811	61,461	59,506
Other Depreciation and Amortization	31,365	29,788	93,272	87,272
Other regulatory charges (credits) - net	33,550	27,619	85,064	61,879
Costs and Expenses	377,265	353,916	1,029,972	1,009,939
OPERATING INCOME	99,966	78,993	199,685	165,385
OTHER INCOME
Allowance for equity funds used during construction	2,222	1,849	5,716	4,762
Investment Income, Net	601	244	1,698	656
Miscellaneous - net	468	1,255	(154)	679
TOTAL	3,291	3,348	7,260	6,097
INTEREST EXPENSE
Interest expense	21,760	21,714	65,646	64,949
Allowance for borrowed funds used during construction	(1,253)	(1,134)	(3,224)	(2,896)
TOTAL	20,507	20,580	62,422	62,053
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	82,750	61,761	144,523	109,429
Income taxes	16,904	22,173	30,538	37,886
Net Income (Loss) Available to Common Stockholders, Basic	65,846	39,588	113,985	71,543
Entergy Texas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	477,231	432,909	1,229,657	1,175,324
Entergy Texas [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	0		0
Entergy Texas [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	153,673	163,532	463,933	474,241
System Energy [Member]
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	14,484	16,170	44,939	53,164
Nuclear refueling outage expenses	5,906	4,435	12,698	13,595
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	48,969	49,871	143,003	149,325
Decommissioning	8,626	8,290	25,624	34,974
Taxes, Other	7,106	6,679	21,069	19,767
Other Depreciation and Amortization	4,355	34,524	71,143	105,152
Other regulatory charges (credits) - net	7,398	(2,843)	(15,080)	(24,626)
Costs and Expenses	96,844	117,126	303,396	351,351
OPERATING INCOME	(17,879)	38,980	36,468	124,498
OTHER INCOME
Allowance for equity funds used during construction	2,028	1,736	7,032	4,148
Investment Income, Net	23,738	6,624	33,567	15,021
Miscellaneous - net	(1,421)	(1,651)	(4,391)	(5,139)
TOTAL	24,345	6,709	36,208	14,030
INTEREST EXPENSE
Interest expense	9,753	9,169	28,734	27,469
Allowance for borrowed funds used during construction	(515)	(425)	(1,783)	(1,014)
TOTAL	9,238	8,744	26,951	26,455
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	(2,772)	36,945	45,725	112,073
Income taxes	(25,744)	16,362	(22,942)	51,793
Net Income (Loss) Available to Common Stockholders, Basic	22,972	20,583	68,667	60,280
System Energy [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 78,965	$ 156,106	$ 339,864	$ 475,849

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017
OPERATING ACTIVITIES
Consolidated net income	[1]	$ 924,877	$ 901,064
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		1,517,344	1,561,565
Deferred income taxes, investment tax credits, and non-current taxes accrued		82,641	(90,607)
Impairment of Long-Lived Assets Held-for-use		210,263	241,838
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property		0	(16,270)
Changes in working capital:
Receivables		(153,703)	(198,029)
Fuel inventory		49,728	20,746
Accounts payable		79,949	(75,962)
Taxes accrued		43,510	66,895
Interest accrued		(9,398)	(6,111)
Deferred fuel costs		(25,284)	(117,636)
Other working capital accounts		(86,063)	(81,779)
Changes in provisions for estimated losses		28,599	(10,073)
Changes in other regulatory assets		207,135	117,430
Increase (Decrease) in Regulatory Liabilities		(413,684)	22,124
Changes in pensions and other postretirement liabilities		(345,526)	(354,297)
Other Noncash Income (Expense)		(250,884)	(268,147)
Net cash flow provided by operating activities		1,859,504	1,712,751
INVESTING ACTIVITIES
Construction/capital expenditures		(2,883,047)	(2,622,104)
Allowance for equity funds used during construction		92,829	66,437
Nuclear fuel purchases		(170,819)	(226,054)
Payments for Nuclear Fuel		(170,819)	(226,054)
Payments to storm reserve escrow account		(4,515)	(1,925)
Receipts from storm reserve escrow account		0	8,836
Increase in other investments		(36,140)	(112,217)
Proceeds from Sale of Productive Assets		12,915	100,000
Proceeds from nuclear decommissioning trust fund sales		4,177,919	1,902,783
Investment in nuclear decommissioning trust funds		(4,187,161)	(1,988,634)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		0	25,493
Proceeds from insurance		10,523	26,157
Changes in securitization account		(12,985)	(6,494)
Net cash flow used in investing activities		(3,000,481)	(2,827,722)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		5,604,131	1,222,606
Common stock and treasury stock		24,646	15,121
Retirement of long-term debt		(4,181,820)	(1,222,915)
Changes in credit borrowings and commercial paper - net		368,370	937,677
Dividends paid:
Common stock		(482,865)	(468,396)
Preferred stock	[1]	(10,317)	(10,338)
Other		25,540	(337)
Net cash flow provided by financing activities		1,347,685	473,418
Net increase (decrease) in cash and cash equivalents		206,708	(641,553)
Cash and cash equivalents at beginning of period		781,273	1,187,844
Cash and cash equivalents at end of period		987,981	546,291
Cash paid / (received) during the period for:
Interest - net of amount capitalized		558,381	507,912
Income taxes		18,200	(11,883)
Entergy Arkansas [Member]
OPERATING ACTIVITIES
Consolidated net income		247,701	145,492
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		335,939	311,725
Deferred income taxes, investment tax credits, and non-current taxes accrued		28,463	78,390
Changes in working capital:
Receivables		(33,422)	(45,180)
Fuel inventory		7,523	10,089
Accounts payable		(20,904)	(78,396)
Taxes accrued		30,686	15,367
Interest accrued		13,558	12,436
Deferred fuel costs		24,463	(53,664)
Other working capital accounts		(8,827)	(6,762)
Changes in provisions for estimated losses		10,013	10,094
Changes in other regulatory assets		22,574	(4,680)
Increase (Decrease) in Regulatory Liabilities		(218,518)	43,473
Changes in pensions and other postretirement liabilities		(64,461)	(73,107)
Other Noncash Income (Expense)		(12,203)	2,274
Net cash flow provided by operating activities		362,585	367,551
INVESTING ACTIVITIES
Construction/capital expenditures		(517,882)	(558,985)
Allowance for equity funds used during construction		12,572	14,521
Change in money pool receivable - net		(13,421)	0
Nuclear fuel purchases		(79,142)	(95,289)
Payments for Nuclear Fuel		(79,142)	(95,289)
Proceeds from sale of nuclear fuel		31,897	51,029
Proceeds from nuclear decommissioning trust fund sales		259,331	219,223
Investment in nuclear decommissioning trust funds		(269,913)	(228,740)
Proceeds from insurance		7,043	0
Changes in securitization account		(4,821)	(3,619)
Change in other investments		(1)	(65,981)
Net cash flow used in investing activities		(574,337)	(667,841)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		658,427	222,717
Retirement of long-term debt		(372,447)	(6,803)
Change in money pool payable - net		(166,137)	43,882
Changes in credit borrowings and commercial paper - net		(49,974)	23,257
Dividends paid:
Preferred stock		(1,071)	(1,071)
Other		8,520	(1,737)
Net cash flow provided by financing activities		427,318	280,245
Net increase (decrease) in cash and cash equivalents		215,566	(20,045)
Cash and cash equivalents at beginning of period		6,216	20,509
Cash and cash equivalents at end of period		221,782	464
Cash paid / (received) during the period for:
Interest - net of amount capitalized		74,966	70,321
Proceeds from Contributions from Parent		350,000	0
Entergy Louisiana [Member]
OPERATING ACTIVITIES
Consolidated net income		514,260	405,141
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		490,638	458,963
Deferred income taxes, investment tax credits, and non-current taxes accrued		167,603	303,397
Changes in working capital:
Receivables		(61,281)	(92,610)
Fuel inventory		6,120	7,643
Accounts payable		(20,481)	31,865
Taxes accrued		(22,893)	97,138
Interest accrued		2,382	9,149
Deferred fuel costs		(25,781)	(37,753)
Other working capital accounts		(5,086)	(49,266)
Changes in provisions for estimated losses		7,800	(6,331)
Changes in other regulatory assets		49,245	60,014
Increase (Decrease) in Regulatory Liabilities		(29,943)	(72,060)
Changes in pensions and other postretirement liabilities		(59,305)	(70,489)
Other Noncash Income (Expense)		(69,978)	(117,625)
Net cash flow provided by operating activities		943,300	927,176
INVESTING ACTIVITIES
Construction/capital expenditures		(1,322,633)	(1,177,121)
Allowance for equity funds used during construction		57,292	34,492
Change in money pool receivable - net		(2,444)	(50,396)
Nuclear fuel purchases		(32,362)	(159,637)
Payments for Nuclear Fuel		(32,362)	(159,637)
Proceeds from sale of nuclear fuel		54,088	28,884
Payments to storm reserve escrow account		(3,297)	(1,422)
Receipts from storm reserve escrow account		0	8,836
Increase in other investments		0	(33,324)
Proceeds from nuclear decommissioning trust fund sales		943,306	176,056
Investment in nuclear decommissioning trust funds		(973,218)	(204,500)
Proceeds from insurance		3,480	5,305
Changes in securitization account		(8,056)	(6,538)
Net cash flow used in investing activities		(1,283,844)	(1,379,365)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		1,950,482	646,850
Retirement of long-term debt		(1,338,227)	(296,359)
Changes in credit borrowings and commercial paper - net		(43,540)	36,762
Dividends paid:
Common stock		(56,000)	(91,250)
Other		5,507	(2,141)
Net cash flow provided by financing activities		518,222	293,862
Net increase (decrease) in cash and cash equivalents		177,678	(158,327)
Cash and cash equivalents at beginning of period		35,907	213,850
Cash and cash equivalents at end of period		213,585	55,523
Cash paid / (received) during the period for:
Interest - net of amount capitalized		208,028	189,896
Income taxes		(2,973)	(116,937)
Entergy Mississippi [Member]
OPERATING ACTIVITIES
Consolidated net income		111,818	92,006
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		114,293	106,935
Deferred income taxes, investment tax credits, and non-current taxes accrued		40,537	65,204
Changes in working capital:
Receivables		(49,456)	(31,085)
Fuel inventory		33,705	8,059
Accounts payable		(9,845)	(2,644)
Taxes accrued		(24,280)	(5,815)
Interest accrued		(4,767)	(2,366)
Deferred fuel costs		9,826	(27,344)
Other working capital accounts		(8,348)	(279)
Changes in provisions for estimated losses		7,894	(10,274)
Changes in other regulatory assets		26,060	(33,323)
Increase (Decrease) in Regulatory Liabilities		(139,063)	(5,118)
Changes in pensions and other postretirement liabilities		(15,987)	(18,863)
Other Noncash Income (Expense)		125,637	(5,779)
Net cash flow provided by operating activities		218,024	129,314
INVESTING ACTIVITIES
Construction/capital expenditures		(275,189)	(313,910)
Allowance for equity funds used during construction		6,351	6,741
Change in money pool receivable - net		1,633	10,595
Increase in other investments		(960)	(1,207)
Change in other investments		0	(3,185)
Net cash flow used in investing activities		(268,165)	(300,966)
Proceeds from the issuance of:
Change in money pool payable - net		33,816	106,180
Dividends paid:
Common stock		0	(10,500)
Preferred stock		(715)	(715)
Other		10,989	(98)
Net cash flow provided by financing activities		44,090	94,867
Net increase (decrease) in cash and cash equivalents		(6,051)	(76,785)
Cash and cash equivalents at beginning of period		6,096	76,834
Cash and cash equivalents at end of period		45	49
Cash paid / (received) during the period for:
Interest - net of amount capitalized		44,781	38,549
Income taxes		0	(15,087)
Entergy New Orleans [Member]
OPERATING ACTIVITIES
Consolidated net income		50,558	44,389
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		41,756	39,356
Deferred income taxes, investment tax credits, and non-current taxes accrued		25,605	30,834
Changes in working capital:
Receivables		(15,310)	(17,030)
Fuel inventory		495	(490)
Accounts payable		8,868	(4,950)
Taxes accrued		(8,743)	(4,484)
Interest accrued		564	546
Deferred fuel costs		(59)	4,258
Other working capital accounts		(5,062)	(6,750)
Changes in provisions for estimated losses		417	(1,702)
Changes in other regulatory assets		19,068	10,093
Increase (Decrease) in Regulatory Liabilities		(5,353)	(1,131)
Changes in pensions and other postretirement liabilities		(12,956)	(13,793)
Other Noncash Income (Expense)		479	5,094
Net cash flow provided by operating activities		100,327	84,240
INVESTING ACTIVITIES
Construction/capital expenditures		(142,585)	(81,143)
Allowance for equity funds used during construction		3,762	1,656
Change in money pool receivable - net		10,607	(32,067)
Payments to storm reserve escrow account		(905)	(406)
Receipts from storm reserve escrow account		3	0
Changes in securitization account		(4,115)	(2,990)
Change in other investments		0	(1,754)
Net cash flow used in investing activities		(133,233)	(116,704)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		59,590	0
Retirement of long-term debt		(5,342)	(5,114)
Dividends paid:
Common stock		(23,750)	(36,100)
Preferred stock		0	(724)
Other		2,587	216
Net cash flow provided by financing activities		33,085	(41,722)
Net increase (decrease) in cash and cash equivalents		179	(74,186)
Cash and cash equivalents at beginning of period		32,741	103,068
Cash and cash equivalents at end of period		32,920	28,882
Cash paid / (received) during the period for:
Interest - net of amount capitalized		14,584	14,668
Entergy Texas [Member]
OPERATING ACTIVITIES
Consolidated net income		113,985	71,543
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		93,272	87,272
Deferred income taxes, investment tax credits, and non-current taxes accrued		640	36,252
Changes in working capital:
Receivables		(40,287)	(30,030)
Fuel inventory		1,045	(7,371)
Accounts payable		(12,864)	24,711
Taxes accrued		24,476	1,122
Interest accrued		(6,084)	(7,207)
Deferred fuel costs		(33,734)	(3,134)
Other working capital accounts		891	(8,455)
Changes in provisions for estimated losses		1,006	(1,460)
Changes in other regulatory assets		64,311	59,549
Increase (Decrease) in Regulatory Liabilities		15,313	(1,500)
Changes in pensions and other postretirement liabilities		(20,999)	(22,978)
Other Noncash Income (Expense)		(3,294)	(5,360)
Net cash flow provided by operating activities		197,677	192,954
INVESTING ACTIVITIES
Construction/capital expenditures		(291,118)	(243,226)
Allowance for equity funds used during construction		5,820	4,879
Proceeds from Sale of Other Assets, Investing Activities		3,753	0
Change in money pool receivable - net		43,686	681
Increase in other investments		0	2,431
Changes in securitization account		4,009	6,653
Net cash flow used in investing activities		(233,850)	(228,582)
Proceeds from the issuance of:
Retirement of long-term debt		(60,500)	(58,076)
Change in money pool payable - net		0	89,312
Dividends paid:
Other		1,657	(287)
Net cash flow provided by financing activities		(58,843)	30,949
Net increase (decrease) in cash and cash equivalents		(95,016)	(4,679)
Cash and cash equivalents at beginning of period		115,513	6,181
Cash and cash equivalents at end of period		20,497	1,502
Cash paid / (received) during the period for:
Interest - net of amount capitalized		69,669	70,237
Income taxes		(624)	(1,446)
System Energy [Member]
OPERATING ACTIVITIES
Consolidated net income		68,667	60,280
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		133,877	184,625
Deferred income taxes, investment tax credits, and non-current taxes accrued		14,159	44,017
Changes in working capital:
Receivables		20,806	21,147
Accounts payable		22,637	2,344
Taxes accrued		(1,017)	2,956
Interest accrued		2,311	401
Other working capital accounts		(52,524)	7,605
Changes in other regulatory assets		(4,773)	1,196
Increase (Decrease) in Regulatory Liabilities		(36,119)	53,519
Changes in pensions and other postretirement liabilities		(11,629)	(14,665)
Other Noncash Income (Expense)		(24,839)	(83,940)
Net cash flow provided by operating activities		131,556	279,485
INVESTING ACTIVITIES
Construction/capital expenditures		(166,458)	(60,041)
Allowance for equity funds used during construction		7,032	4,148
Change in money pool receivable - net		95,302	(202,658)
Nuclear fuel purchases		(110,485)	(24,239)
Payments for Nuclear Fuel		(110,485)	(24,239)
Proceeds from sale of nuclear fuel		12,867	60,188
Proceeds from nuclear decommissioning trust fund sales		357,209	308,134
Investment in nuclear decommissioning trust funds		(365,040)	(336,069)
Change in other investments		0	(9,061)
Net cash flow used in investing activities		(169,573)	(259,598)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		211,985	0
Retirement of long-term debt		(124,304)	(50,003)
Changes in credit borrowings and commercial paper - net		(17,830)	14,858
Dividends paid:
Common stock		(64,480)	(85,610)
Other		0	(28)
Net cash flow provided by financing activities		5,371	(120,783)
Net increase (decrease) in cash and cash equivalents		(32,646)	(100,896)
Cash and cash equivalents at beginning of period		287,187	245,863
Cash and cash equivalents at end of period		254,541	144,967
Cash paid / (received) during the period for:
Interest - net of amount capitalized		$ 10,308	$ 26,251
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2018 and 2017 include $10.3 million and $10.3 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017	Sep. 30, 2017	Dec. 31, 2016
Cash and cash equivalents:
Cash	$ 64,787	$ 56,629
Temporary cash investments	923,194	724,644
Total cash and cash equivalents	987,981	781,273	$ 546,291	$ 1,187,844
Securitization recovery trust account	58,000	45,000
Accounts receivable:
Customer	789,633	673,347
Allowance for doubtful accounts	(15,589)	(13,587)
Other	166,222	169,377
Accrued unbilled revenues	426,387	383,813
Total accounts receivable	1,366,653	1,212,950
Deferred fuel costs	61,309	95,746
Fuel inventory - at average cost	132,916	182,643
Public Utilities, Inventory	747,770	723,222
Deferred nuclear refueling outage costs	149,810	133,164
Prepaid Expense and Other Assets, Current	248,107	156,333
TOTAL	3,694,546	3,285,331
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	198	198
Decommissioning trust funds	7,444,346	7,211,993
Non-utility property - at cost (less accumulated depreciation)	302,784	260,980
Other	436,527	441,862
TOTAL	8,183,855	7,915,033
PROPERTY, PLANT, AND EQUIPMENT
Electric	48,362,347	47,287,370
Property under capital lease	620,419	620,544
Natural gas	488,169	453,162
Construction work in progress	2,832,826	1,980,508
Nuclear fuel	846,845	923,200
TOTAL PROPERTY, PLANT, AND EQUIPMENT	53,150,606	51,264,784
Less - accumulated depreciation and amortization	22,057,870	21,600,424
PROPERTY, PLANT, AND EQUIPMENT - NET	31,092,736	29,664,360
Regulatory assets:
Other regulatory assets	4,728,555	4,935,689
Deferred Fuel Cost Non Current	239,446	239,298
Goodwill	377,172	377,172
Deferred Income Tax Assets, Net	21,307	178,204
Other	133,555	112,062
Deferred Costs and Other Assets	5,500,035	5,842,425
TOTAL ASSETS	48,471,172	46,707,149
CURRENT LIABILITIES
Currently maturing long-term debt	735,009	760,007
Short-term borrowings	1,946,677	1,578,308
Accounts payable	1,392,114	1,452,216
Customer deposits	409,153	401,330
Taxes Payable, Current	258,477	214,967
Interest accrued	178,573	187,972
Deferred fuel costs	86,949	146,522
Obligations under capital leases	1,466	1,502
Pension and other postretirement liabilities	57,471	71,612
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	500,419	0
Other	184,255	221,771
TOTAL	5,750,563	5,036,207
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	4,427,744	4,466,503
Accumulated deferred investment tax credits	213,237	219,634
Regulatory liability for income taxes - net	1,802,528	2,900,204
Obligations under capital leases	20,887	22,015
Other regulatory liabilities	1,772,093	1,588,520
Decommissioning and asset retirement cost liabilities	6,555,835	6,185,814
Loss Contingency Accrual	506,959	478,273
Pension and other postretirement liabilities	2,579,270	2,910,654
Long-term debt	15,780,827	14,315,259
Deferred Credits and Other Liabilities	450,746	393,748
TOTAL	34,110,126	33,480,624
Subsidiaries' preferred stock without sinking fund	197,771	197,803
Common Shareholders' Equity:
Common stock	2,548	2,548
Additional Paid in Capital, Common Stock	5,441,696	5,433,433
Retained earnings	8,953,611	7,977,702
Accumulated other comprehensive loss	(632,126)	(23,531)	111,678	(34,971)
Less - treasury stock, at cost	5,353,017	5,397,637
TOTAL	8,412,712	7,992,515	8,690,237	8,081,809
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	48,471,172	46,707,149
Entergy Arkansas [Member]
Cash and cash equivalents:
Cash	13,121	6,184
Temporary cash investments	208,661	32
Total cash and cash equivalents	221,782	6,216	464	20,509
Securitization recovery trust account	8,570	3,748
Accounts receivable:
Customer	141,294	110,016
Allowance for doubtful accounts	(1,420)	(1,063)
Associated companies	57,253	38,765
Other	51,756	65,209
Accrued unbilled revenues	116,007	105,120
Total accounts receivable	364,890	318,047
Deferred fuel costs	38,691	63,302
Fuel inventory - at average cost	21,835	29,358
Public Utilities, Inventory	196,623	192,853
Deferred nuclear refueling outage costs	57,683	56,485
Prepaid Expense and Other Assets, Current	22,316	12,108
TOTAL	932,390	682,117
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	996,857	944,890
Other	785	3,160
TOTAL	997,642	948,050
PROPERTY, PLANT, AND EQUIPMENT
Electric	11,376,058	11,059,538
Construction work in progress	350,554	280,888
Nuclear fuel	240,582	277,345
TOTAL PROPERTY, PLANT, AND EQUIPMENT	11,967,194	11,617,771
Less - accumulated depreciation and amortization	4,908,917	4,762,352
PROPERTY, PLANT, AND EQUIPMENT - NET	7,058,277	6,855,419
Regulatory assets:
Other regulatory assets	1,544,863	1,567,437
Deferred Fuel Cost Non Current	67,244	67,096
Other	18,252	13,910
Deferred Costs and Other Assets	1,630,359	1,648,443
TOTAL ASSETS	10,618,668	10,134,029
CURRENT LIABILITIES
Short-term borrowings	0	49,974
Associated companies accounts payable	183,372	365,915
Accounts payable	172,820	215,942
Customer deposits	99,138	97,687
Taxes Payable, Current	78,007	47,321
Interest accrued	31,773	18,215
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	179,712	0
Other	32,411	29,922
TOTAL	777,233	824,976
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	1,235,625	1,190,669
Accumulated deferred investment tax credits	33,203	34,104
Regulatory liability for income taxes - net	533,179	985,823
Other regulatory liabilities	418,005	363,591
Decommissioning and asset retirement cost liabilities	1,026,816	981,213
Loss Contingency Accrual	44,742	34,729
Pension and other postretirement liabilities	288,870	353,274
Long-term debt	3,242,282	2,952,399
Deferred Credits and Other Liabilities	13,979	5,147
TOTAL	6,836,701	6,900,949
Subsidiaries' preferred stock without sinking fund	31,350	31,350
Common Shareholders' Equity:
Common stock	470	470
Additional Paid in Capital, Common Stock	1,140,264	790,264
Retained earnings	1,832,650	1,586,020
TOTAL	2,973,384	2,376,754	2,397,738	2,253,317
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	10,618,668	10,134,029
Entergy Louisiana [Member]
Cash and cash equivalents:
Cash	363	5,836
Temporary cash investments	213,222	30,071
Total cash and cash equivalents	213,585	35,907	55,523	213,850
Securitization recovery trust account	10,000	2,000
Accounts receivable:
Customer	296,121	254,308
Allowance for doubtful accounts	(9,634)	(8,430)
Associated companies	137,252	143,524
Other	65,677	60,893
Accrued unbilled revenues	177,722	153,118
Total accounts receivable	667,138	603,413
Fuel inventory - at average cost	33,608	39,728
Public Utilities, Inventory	326,192	299,881
Deferred nuclear refueling outage costs	29,313	65,711
Prepaid Expense and Other Assets, Current	47,105	34,035
Prepaid Taxes	4,736	0
TOTAL	1,321,677	1,078,675
Investments in and Advances to Affiliates, at Fair Value	1,390,587	1,390,587
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,395,216	1,312,073
Non-utility property - at cost (less accumulated depreciation)	285,099	245,255
Storm Reserve Escrow Account	288,056	284,759
Other	14,773	18,999
TOTAL	3,373,731	3,251,673
PROPERTY, PLANT, AND EQUIPMENT
Electric	20,204,568	19,678,536
Natural gas	208,480	191,899
Construction work in progress	1,737,898	1,281,452
Nuclear fuel	219,139	337,402
TOTAL PROPERTY, PLANT, AND EQUIPMENT	22,370,085	21,489,289
Less - accumulated depreciation and amortization	8,787,797	8,703,047
PROPERTY, PLANT, AND EQUIPMENT - NET	13,582,288	12,786,242
Regulatory assets:
Other regulatory assets	1,096,597	1,145,842
Deferred Fuel Cost Non Current	168,122	168,122
Other	27,124	18,310
Deferred Costs and Other Assets	1,291,843	1,332,274
TOTAL ASSETS	19,569,539	18,448,864
CURRENT LIABILITIES
Currently maturing long-term debt	3	675,002
Short-term borrowings	0	43,540
Associated companies accounts payable	83,469	126,685
Accounts payable	337,473	404,374
Customer deposits	155,263	150,623
Taxes Payable, Current	0	18,157
Interest accrued	77,910	75,528
Deferred fuel costs	45,666	71,447
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	157,173	0
Other	60,072	79,037
TOTAL	917,029	1,644,393
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	2,244,767	2,050,371
Accumulated deferred investment tax credits	118,217	121,870
Regulatory liability for income taxes - net	470,300	725,368
Other regulatory liabilities	829,011	761,059
Decommissioning and asset retirement cost liabilities	1,272,795	1,140,461
Loss Contingency Accrual	310,248	302,448
Pension and other postretirement liabilities	688,498	748,384
Long-term debt	6,761,120	5,469,069
Deferred Credits and Other Liabilities	195,776	176,637
TOTAL	12,890,732	11,495,667
Common Shareholders' Equity:
Accumulated other comprehensive loss	(57,951)	(46,400)
Members' Equity	5,819,729	5,355,204
TOTAL	5,761,778	5,308,804	5,394,588	5,081,809
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	19,569,539	18,448,864
Entergy Mississippi [Member]
Cash and cash equivalents:
Cash	38	1,607
Temporary cash investments	7	4,489
Total cash and cash equivalents	45	6,096	49	76,834
Accounts receivable:
Customer	102,986	72,039
Allowance for doubtful accounts	(830)	(574)
Associated companies	54,578	45,081
Other	16,294	9,738
Accrued unbilled revenues	55,335	54,256
Total accounts receivable	228,363	180,540
Deferred fuel costs	22,618	32,444
Fuel inventory - at average cost	11,901	45,606
Public Utilities, Inventory	46,041	42,571
Prepaid Expense and Other Assets, Current	10,674	7,041
TOTAL	319,642	314,298
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,580	4,592
Escrow accounts	32,284	31,969
TOTAL	36,864	36,561
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,624,415	4,660,297
Property under capital lease	0	125
Construction work in progress	181,766	149,367
TOTAL PROPERTY, PLANT, AND EQUIPMENT	4,806,181	4,809,789
Less - accumulated depreciation and amortization	1,652,552	1,681,306
PROPERTY, PLANT, AND EQUIPMENT - NET	3,153,629	3,128,483
Regulatory assets:
Other regulatory assets	371,849	397,909
Other	4,859	2,124
Deferred Costs and Other Assets	376,708	400,033
TOTAL ASSETS	3,886,843	3,879,375
CURRENT LIABILITIES
Currently maturing long-term debt	150,000	0
Associated companies accounts payable	67,933	55,689
Accounts payable	80,909	77,326
Customer deposits	84,260	83,654
Taxes Payable, Current	58,563	82,843
Interest accrued	18,134	22,901
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	9,262	0
Other	10,169	12,785
TOTAL	479,230	335,198
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	533,861	488,806
Accumulated deferred investment tax credits	8,747	8,867
Regulatory liability for income taxes - net	239,118	411,011
Decommissioning and asset retirement cost liabilities	9,977	9,219
Loss Contingency Accrual	52,658	44,764
Pension and other postretirement liabilities	85,509	101,498
Long-term debt	1,120,830	1,270,122
Deferred Credits and Other Liabilities	47,559	11,639
TOTAL	2,098,259	2,345,926
Subsidiaries' preferred stock without sinking fund	20,381	20,381
Common Shareholders' Equity:
Common stock	199,326	199,326
Additional Paid in Capital, Common Stock	167	167
Retained earnings	1,089,480	978,377
TOTAL	1,288,973	1,177,870	1,175,582	1,094,791
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	3,886,843	3,879,375
Entergy New Orleans [Member]
Cash and cash equivalents:
Cash	26	30
Temporary cash investments	32,894	32,711
Total cash and cash equivalents	32,920	32,741	28,882	103,068
Securitization recovery trust account	5,570	1,455
Accounts receivable:
Customer	61,107	51,006
Allowance for doubtful accounts	(3,135)	(3,057)
Associated companies	17,464	22,976
Other	5,986	6,471
Accrued unbilled revenues	21,315	20,638
Total accounts receivable	102,737	98,034
Fuel inventory - at average cost	1,395	1,890
Public Utilities, Inventory	12,944	10,381
Prepaid Expense and Other Assets, Current	11,160	8,030
Prepaid Taxes	35,222	26,479
TOTAL	201,948	179,010
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	1,016	1,016
Storm Reserve Escrow Account	80,448	79,546
Other	0	2,373
TOTAL	81,464	82,935
PROPERTY, PLANT, AND EQUIPMENT
Electric	1,334,227	1,302,235
Natural gas	279,689	261,263
Construction work in progress	139,839	46,993
TOTAL PROPERTY, PLANT, AND EQUIPMENT	1,753,755	1,610,491
Less - accumulated depreciation and amortization	659,315	631,178
PROPERTY, PLANT, AND EQUIPMENT - NET	1,094,440	979,313
Regulatory assets:
Other regulatory assets	232,365	251,433
Deferred Fuel Cost Non Current	4,080	4,080
Other	1,471	1,065
Deferred Costs and Other Assets	237,916	256,578
TOTAL ASSETS	1,615,768	1,497,836
CURRENT LIABILITIES
Notes Payable, Related Parties, Current	2,077	2,077
Associated companies accounts payable	35,094	47,472
Accounts payable	67,197	29,777
Customer deposits	28,617	28,442
Interest accrued	6,051	5,487
Deferred fuel costs	7,715	7,774
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	26,200	0
Other	7,459	7,351
TOTAL	180,410	128,380
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	310,767	283,302
Accumulated deferred investment tax credits	2,242	2,323
Regulatory liability for income taxes - net	78,164	119,259
Decommissioning and asset retirement cost liabilities	3,236	3,076
Loss Contingency Accrual	85,500	85,083
Pension and other postretirement liabilities	7,774	20,755
Long-term debt	473,147	418,447
Deferred Credits and Other Liabilities	15,826	5,317
TOTAL	993,002	953,908
Common Shareholders' Equity:
Common stock	442,356	415,548
TOTAL	442,356	415,548	434,511	426,946
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	1,615,768	1,497,836
Notes Payable, Related Parties, Noncurrent	16,346	16,346
Entergy Texas [Member]
Cash and cash equivalents:
Cash	1,541	32
Temporary cash investments	18,956	115,481
Total cash and cash equivalents	20,497	115,513	1,502	6,181
Securitization recovery trust account	33,675	37,683
Accounts receivable:
Customer	105,040	74,382
Allowance for doubtful accounts	(570)	(463)
Associated companies	51,624	90,629
Other	9,560	9,831
Accrued unbilled revenues	56,008	50,682
Total accounts receivable	221,662	225,061
Fuel inventory - at average cost	41,686	42,731
Public Utilities, Inventory	40,083	38,605
Prepaid Expense and Other Assets, Current	19,968	19,710
TOTAL	377,571	479,303
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	458	457
Non-utility property - at cost (less accumulated depreciation)	376	376
Other	18,999	19,235
TOTAL	19,833	20,068
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,693,662	4,569,295
Construction work in progress	223,279	102,088
TOTAL PROPERTY, PLANT, AND EQUIPMENT	4,916,941	4,671,383
Less - accumulated depreciation and amortization	1,650,889	1,579,387
PROPERTY, PLANT, AND EQUIPMENT - NET	3,266,052	3,091,996
Regulatory assets:
Other regulatory assets	597,087	661,398
Other	32,118	26,973
Deferred Costs and Other Assets	629,205	688,371
TOTAL ASSETS	4,292,661	4,279,738
CURRENT LIABILITIES
Currently maturing long-term debt	500,000	0
Associated companies accounts payable	42,825	59,347
Accounts payable	106,968	126,095
Customer deposits	41,875	40,925
Taxes Payable, Current	70,135	45,659
Interest accrued	19,472	25,556
Deferred fuel costs	33,567	67,301
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	91,126	0
Other	9,792	8,132
TOTAL	915,760	373,015
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	548,173	544,642
Accumulated deferred investment tax credits	11,403	11,983
Regulatory liability for income taxes - net	320,640	412,620
Other regulatory liabilities	23,017	6,850
Decommissioning and asset retirement cost liabilities	7,123	6,835
Loss Contingency Accrual	11,121	10,115
Pension and other postretirement liabilities	0	17,853
Long-term debt	1,027,817	1,587,150
Deferred Credits and Other Liabilities	53,455	48,508
TOTAL	2,002,749	2,646,556
Common Shareholders' Equity:
Common stock	49,452	49,452
Additional Paid in Capital, Common Stock	596,994	596,994
Retained earnings	727,706	613,721
TOTAL	1,374,152	1,260,167	1,140,537	1,068,994
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	4,292,661	4,279,738
System Energy [Member]
Cash and cash equivalents:
Cash	153	78
Temporary cash investments	254,388	287,109
Total cash and cash equivalents	254,541	287,187	144,967	245,863
Accounts receivable:
Associated companies	55,727	170,149
Other	4,840	6,526
Total accounts receivable	60,567	176,675
Public Utilities, Inventory	93,074	88,424
Deferred nuclear refueling outage costs	53,174	7,908
Prepaid Expense and Other Assets, Current	5,099	2,489
TOTAL	466,455	562,683
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	952,413	905,686
TOTAL	952,413	905,686
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,434,393	4,327,849
Property under capital lease	588,281	588,281
Construction work in progress	71,482	69,937
Nuclear fuel	259,450	207,513
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,353,606	5,193,580
Less - accumulated depreciation and amortization	3,191,434	3,175,018
PROPERTY, PLANT, AND EQUIPMENT - NET	2,162,172	2,018,562
Regulatory assets:
Other regulatory assets	449,100	444,327
Other	4,835	7,629
Deferred Costs and Other Assets	453,935	451,956
TOTAL ASSETS	4,034,975	3,938,887
CURRENT LIABILITIES
Currently maturing long-term debt	85,006	85,004
Short-term borrowings	0	17,830
Associated companies accounts payable	38,522	16,878
Accounts payable	62,015	62,868
Taxes Payable, Current	45,567	46,584
Interest accrued	15,700	13,389
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	36,946	0
Other	2,436	2,434
TOTAL	286,192	244,987
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	795,150	776,420
Accumulated deferred investment tax credits	38,447	39,406
Regulatory liability for income taxes - net	161,126	246,122
Other regulatory liabilities	467,922	455,991
Decommissioning and asset retirement cost liabilities	887,288	861,664
Pension and other postretirement liabilities	110,245	121,874
Long-term debt	554,449	466,484
Deferred Credits and Other Liabilities	19,160	15,130
TOTAL	3,033,787	2,983,091
Common Shareholders' Equity:
Common stock	601,850	658,350
Retained earnings	113,146	52,459
TOTAL	714,996	710,809	$ 713,493	$ 738,823
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$ 4,034,975	$ 3,938,887

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Securitization property	$ 388,391	$ 485,031
Securitization bonds	$ 462,889	$ 544,921
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	500,000,000	500,000,000
Common stock, shares issued	254,752,788	254,752,788
Treasury stock, shares	73,621,473	74,235,135
Entergy Arkansas [Member]
Securitization property	$ 17,247	$ 28,583
Securitization bonds	$ 27,958	$ 34,662
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	325,000,000	325,000,000
Common stock, shares issued	46,980,196	46,980,196
Common stock, shares outstanding	46,980,196	46,980,196
Entergy Louisiana [Member]
Securitization property	$ 54,910	$ 71,367
Securitization bonds	$ 67,634	$ 77,736
Entergy Mississippi [Member]
Common stock, shares authorized	12,000,000	12,000,000
Common stock, shares issued	8,666,357	8,666,357
Common stock, shares outstanding	8,666,357	8,666,357
Entergy New Orleans [Member]
Securitization property	$ 62,857	$ 72,095
Securitization bonds	69,259	74,419
Entergy Texas [Member]
Securitization property	253,493	313,123
Securitization bonds	$ 298,038	$ 358,104
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 Arkansas [Member]Paid In Capital [Member]	Entergy Arkansas [Member]Retained Earnings [Member]	Entergy Arkansas [Member]Common Stock [Member]	Entergy Louisiana [Member]	Entergy Louisiana [Member]Member's Equity [Member]	Entergy Louisiana [Member]Accumulated Other Comprehensive Income [Member]	Entergy Mississippi [Member]	Entergy Mississippi [Member]Capital Stock Expense and Other [Member]	Entergy Mississippi [Member]Retained Earnings [Member]	Entergy Mississippi [Member]Common Stock [Member]	Entergy New Orleans [Member]	Entergy New Orleans [Member]Common Stock [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	$ 8,081,809		$ 0		$ 5,417,245	$ 8,195,571		$ (34,971)	$ 2,548	$ (5,498,584)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest											$ 2,253,317	$ 790,243	$ 1,462,604	$ 470	$ 5,081,809	$ 5,130,251	$ (48,442)	$ 1,094,791	$ 167	$ 895,298	$ 199,326	$ 426,946		$ 1,068,994	$ 481,994	$ 537,548	$ 49,452	$ 738,823	$ 59,473	$ 679,350
Consolidated net income	901,064	[1]	10,338	[1]	0	890,726	[1]	0	0	0	145,492	0	145,492	0	405,141	405,141	0	92,006	0	92,006	0	44,389		71,543	0	71,543	0	60,280	60,280	0
Dividends, Common Stock, Cash																		10,500	0	10,500	0							85,610	85,610	0
Other comprehensive income (loss)	146,649		0		0	0		146,649	0	0					(1,050)	0	(1,050)
Common stock issuances related to stock plans	39,449		0		3,363	0		0	0	36,086
Common stock	(468,396)		0		0	(468,396)		0	0	0					(91,250)	(91,250)	0	(10,500)				(36,100)						(85,610)
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable	10,338	[1]	10,338	[1]	0	0		0	0	0	1,071	0	1,071	0				715	0	715	0	724	$ (724)
Other															(62)	(62)	0
Proceeds from Contributions from Parent											0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	8,690,237		0		5,420,608	8,617,901		111,678	2,548	(5,462,498)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest											2,397,738	790,243	1,607,025	470	5,394,588	5,444,080	(49,492)	1,175,582	167	976,089	199,326	434,511		1,140,537	481,994	609,091	49,452	713,493	34,143	679,350
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	790,264	1,586,020	470	5,308,804	5,355,204	(46,400)	1,177,870	167	978,377	199,326	415,548		1,260,167	596,994	613,721	49,452	710,809	52,459	658,350
Consolidated net income	924,877	[1]	10,317	[1]	0	914,560	[1]	0	0	0	247,701	0	247,701	0	514,260	514,260	0	111,818	0	111,818	0	50,558		113,985	0	113,985	0	68,667	68,667	0
Other comprehensive income (loss)	8,517		0		0	0		8,517	0	0					(1,502)	0	(1,502)
Common stock issuances related to stock plans	52,883		0		8,263	0		0	0	44,620
Common stock	(482,865)		0		0	(482,865)		0	0	0					(56,000)	(56,000)	0	0				(23,750)						(64,480)	(7,980)	(56,500)
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable	10,317	[1]	10,317	[1]	0	0		0	0	0	1,071	0	1,071	0				715	0	715	0	0
Other															3	3	0
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect	(16,538)	[1]	0	[1]	0	(32,043)		15,505	0	0					(3,787)	6,262	(10,049)
Proceeds from Contributions from Parent											350,000	350,000	0	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 8,412,712		$ 0		$ 5,441,696	$ 8,953,611		$ (632,126)	$ 2,548	$ (5,353,017)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest											$ 2,973,384	$ 1,140,264	$ 1,832,650	$ 470	$ 5,761,778	$ 5,819,729	$ (57,951)	$ 1,288,973	$ 167	$ 1,089,480	$ 199,326	$ 442,356		$ 1,374,152	$ 596,994	$ 727,706	$ 49,452	$ 714,996	$ 113,146	$ 601,850
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2018 and 2017 include $10.3 million and $10.3 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Consolidated Statements Of Ch_2

Consolidated Statements Of Changes In Equity (Parenthetical) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Statement of Stockholders' Equity [Abstract]
Preferred dividends on subsidiaries' preferred stock	$ 10.3	$ 10.3

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018		Sep. 30, 2017
Net income	$ 539,818	$ 401,644	$ 924,877	[1]	$ 901,064	[1]
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss)	(32,004)	13,213	(1,645)		32,634
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	15,265	12,297	47,404		31,845
Net unrealized investment gains	(1,745)	33,395	(37,242)		82,918
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Gain (Loss) Arising During Period, Net of Tax	0	0	0		(748)
Other comprehensive income (loss)	(18,484)	58,905	8,517		146,649
Total comprehensive income	521,334	460,549	933,394		1,047,713
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	3,439	3,446	10,317		10,338
Comprehensive Income Attributable to Entergy Corporation	517,895	457,103	923,077		1,037,375
Entergy Louisiana [Member]
Net income	218,308	186,284	514,260		405,141
Other comprehensive income (loss)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	(500)	(370)	(1,502)		(1,050)
Other comprehensive income (loss)	(500)	(370)	(1,502)		(1,050)
Total comprehensive income	$ 217,808	$ 185,914	$ 512,758		$ 404,091
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2018 and 2017 include $10.3 million and $10.3 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Consolidated Statements Of Co_2

Consolidated Statements Of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Tax	$ (8,517)	$ 7,062	$ (480)	$ 17,387
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	4,126	6,818	12,919	19,034
Other Comprehensive Income (Loss), Securities, Available-for-sale, Tax	(825)	30,644	1,708	72,808
Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Tax	0	0	0	(403)
Entergy Louisiana [Member]
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	$ (177)	$ (232)	$ (530)	$ (756)

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2018
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. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. This action followed NRC inspections to review ANO 1’s and ANO 2’s performance in addressing issues that had previously resulted in classification in Column 4. Pilgrim NRC Oversight and Planned 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 planned shutdown of Pilgrim on May 31, 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. In September 2018 the DOE submitted an offer of judgment to resolve claims in the second round Entergy Nuclear Generation Company case involving Pilgrim. The $62 million offer was accepted by Entergy Nuclear Generation Company, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Nuclear Generation Company. Entergy received payment from the U.S. Treasury in October 2018. 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.
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. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. This action followed NRC inspections to review ANO 1’s and ANO 2’s performance in addressing issues that had previously resulted in classification in Column 4. Pilgrim NRC Oversight and Planned 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 planned shutdown of Pilgrim on May 31, 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. In September 2018 the DOE submitted an offer of judgment to resolve claims in the second round Entergy Nuclear Generation Company case involving Pilgrim. The $62 million offer was accepted by Entergy Nuclear Generation Company, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Nuclear Generation Company. Entergy received payment from the U.S. Treasury in October 2018. 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.
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. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. This action followed NRC inspections to review ANO 1’s and ANO 2’s performance in addressing issues that had previously resulted in classification in Column 4. Pilgrim NRC Oversight and Planned 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 planned shutdown of Pilgrim on May 31, 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. In September 2018 the DOE submitted an offer of judgment to resolve claims in the second round Entergy Nuclear Generation Company case involving Pilgrim. The $62 million offer was accepted by Entergy Nuclear Generation Company, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Nuclear Generation Company. Entergy received payment from the U.S. Treasury in October 2018. 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.
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. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. This action followed NRC inspections to review ANO 1’s and ANO 2’s performance in addressing issues that had previously resulted in classification in Column 4. Pilgrim NRC Oversight and Planned 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 planned shutdown of Pilgrim on May 31, 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. In September 2018 the DOE submitted an offer of judgment to resolve claims in the second round Entergy Nuclear Generation Company case involving Pilgrim. The $62 million offer was accepted by Entergy Nuclear Generation Company, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Nuclear Generation Company. Entergy received payment from the U.S. Treasury in October 2018. 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.
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. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. This action followed NRC inspections to review ANO 1’s and ANO 2’s performance in addressing issues that had previously resulted in classification in Column 4. Pilgrim NRC Oversight and Planned 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 planned shutdown of Pilgrim on May 31, 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. In September 2018 the DOE submitted an offer of judgment to resolve claims in the second round Entergy Nuclear Generation Company case involving Pilgrim. The $62 million offer was accepted by Entergy Nuclear Generation Company, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Nuclear Generation Company. Entergy received payment from the U.S. Treasury in October 2018. 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.
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. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. This action followed NRC inspections to review ANO 1’s and ANO 2’s performance in addressing issues that had previously resulted in classification in Column 4. Pilgrim NRC Oversight and Planned 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 planned shutdown of Pilgrim on May 31, 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. In September 2018 the DOE submitted an offer of judgment to resolve claims in the second round Entergy Nuclear Generation Company case involving Pilgrim. The $62 million offer was accepted by Entergy Nuclear Generation Company, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Nuclear Generation Company. Entergy received payment from the U.S. Treasury in October 2018. 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.
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. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. This action followed NRC inspections to review ANO 1’s and ANO 2’s performance in addressing issues that had previously resulted in classification in Column 4. Pilgrim NRC Oversight and Planned 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 planned shutdown of Pilgrim on May 31, 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. In September 2018 the DOE submitted an offer of judgment to resolve claims in the second round Entergy Nuclear Generation Company case involving Pilgrim. The $62 million offer was accepted by Entergy Nuclear Generation Company, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Nuclear Generation Company. Entergy received payment from the U.S. Treasury in October 2018. 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.

Rate And Regulatory Matters

Rate And Regulatory Matters	9 Months Ended
	Sep. 30, 2018
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 See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements in the Form 10-K for discussion of the effects of the enactment in December 2017 of the Tax Cuts and Jobs Act (the Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. After assessing the activity described in more detail below regarding the status of the proposals the Registrant Subsidiaries made to their regulators for the return of unprotected excess accumulated deferred income taxes to customers, in 2018, Entergy and each of the Registrant Subsidiaries are reclassifying from the regulatory liability for income taxes to current liabilities the portion of their unprotected excess accumulated deferred income taxes that they expect to return to customers over the next twelve months. Entergy Arkansas See the Form 10-K for a discussion of the activity of the APSC and Entergy Arkansas after enactment of the Tax Act in December 2017. The APSC granted Entergy Arkansas’s request for clarification regarding the APSC’s order issued after enactment of the Tax Act. The APSC stated that its order was not a final determination and that the APSC had made no decision at that time on the appropriate final accounting or ratemaking treatment of the amounts in question. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its existing formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider includes a netting adjustment that compares actual annual costs and sales to the projected annual costs and sales used to establish rates. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed below, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true-up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits associated with the Tax Act. For the residential customer class, the unprotected excess accumulated deferred income taxes will be returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, the unprotected excess accumulated deferred income taxes will be returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included, with any over- or under-returned unprotected excess accumulated deferred income taxes to be credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. Entergy Louisiana See the Form 10-K for a discussion of the activity of the LPSC and Entergy Louisiana after enactment of the Tax Act in December 2017. In July 2018 the LPSC issued a proposed rule requiring utilities to adjust rates prospectively to reflect the lower tax rate (either through a formula rate plan or rate case), refund excess tax expense collected since January 1, 2018 until the lower tax rate is reflected in rates (with the refund occurring over one year), and refund excess accumulated deferred income taxes over two years. Entergy Louisiana believes that its formula rate plan settlement, approved in April 2018 and discussed below, addresses fully its obligations regarding the Tax Act and will seek such confirmation in its comments to the proposed rule. In the formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana will return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the parties agreed that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana would establish a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan are established (September 2018), and this regulatory liability will be returned to customers over the next formula rate plan rate-effective period (September 2018 through August 2019). As of September 30, 2018, Entergy Louisiana has a $67 million regulatory liability recorded pursuant to this provision of the settlement. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing, which, as discussed below, Entergy Louisiana filed in June 2018. Entergy Mississippi As discussed in the Form 10-K, after enactment of the Tax Act the MPSC ordered utilities, including Entergy Mississippi, that operate under a formula rate plan to file a description by February 26, 2018, of how the Tax Act will be reflected in the formula rate plan under which the utility operates. Entergy Mississippi's plan, as filed with the MPSC on February 26, 2018, included a request to reflect the changes related to the Tax Act in the 2018 formula rate plan filing. Entergy Mississippi filed its 2018 formula rate plan on March 15, 2018 and included a proposal to return all of its unprotected excess accumulated deferred income taxes to customers through rates or in exchange for other assets, or a combination of both, by the end of 2018. Also, in March 2018 the MPSC issued a subsequent order in its generic tax reform docket ordering utilities, including Entergy Mississippi, to explain the implementation of the utilities tax adjustment clause, or, in the alternative, why the tax adjustment clause is inapplicable; submit an analysis of the ratemaking effects of the Tax Act on current and future revenue requirements for rate schedules that include a gross-up for federal taxes; and make appropriate accounting entries to recognize the removal of excess deferred taxes from the balance of the utility’s accumulated deferred income tax account, or, in the alternative, explain why recording such entries is not appropriate. In April 2018, Entergy Mississippi filed its response to the MPSC stating that the tax adjustment clauses in its base rates are properly implemented through its formula rate plan. Entergy Mississippi also provided analysis of the ratemaking effects of the Tax Act. In June 2018, Entergy Mississippi and the Mississippi Public Utilities Staff entered into and filed a joint stipulation in Entergy Mississippi’s formula rate plan filing that addressed Entergy Mississippi’s 2018 formula rate plan evaluation report and the ratemaking effects of the Tax Act. Also in June 2018 the MPSC approved the stipulation, which provides for incorporating the reduction of the statutory federal income tax rate through the formula rate plan. Entergy Mississippi’s formula rate plan includes a look-back evaluation report filing in March 2019 that will compare actual 2018 results to the allowed return on rate base. The stipulation provides for the flow-back of protected excess accumulated deferred income taxes over approximately 40 years through the formula rate plan. The stipulation also provides for the offset of unprotected excess accumulated deferred income taxes of $127.2 million against net utility plant and $2.2 million against other regulatory assets, and the return to customers of the remaining balance of unprotected excess accumulated deferred income taxes as recovery of a portion of fuel oil inventory and customer bill credits over a three-month period from July 2018 through September 2018, with any true-up to be reflected in the November 2018 power management rider submittal. Entergy Mississippi recorded the reduction against net utility plant and other regulatory assets in June 2018. In third quarter 2018, Entergy Mississippi returned unprotected excess accumulated deferred income taxes of $25.8 million through customer bill credits and $5.8 million through the sale of fuel oil inventory. Entergy New Orleans As discussed in the Form 10-K, after enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy has submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what is presently reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits starting in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at FERC. The agreement in principle was approved by the City Council in June 2018. Entergy Texas As discussed below, in May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflect the inclusion of the federal income tax reductions due to the Tax Act. See the discussion below regarding the terms of an unopposed settlement submitted by the parties to the 2018 rate case that, if approved by the PUCT, establishes the amounts and timing of the return of protected and unprotected excess accumulated deferred income taxes to Entergy Texas customers. 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 are ongoing. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2018, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01547 per kWh to $0.01882 per kWh. The Arkansas Attorney General filed a response to Entergy Arkansas’s annual redetermination filing requesting that the APSC suspend the proposed tariff to investigate the amount of the redetermination or, alternatively, to allow recovery subject to refund. Among the reasons the Attorney General cited for suspension were questions pertaining to how Entergy Arkansas forecasted sales and potential implications of the Tax Act. Entergy Arkansas replied to the Attorney General’s filing and stated that, to the extent there are questions pertaining to its load forecasting or the operation of the energy cost recovery rider, those issues exceed the scope of the instant rate redetermination. Entergy Arkansas also stated that potential effects of the Tax Act are appropriately considered in the APSC’s separate proceeding looking at potential implications of the new tax law. The APSC general staff filed a reply to the Attorney General’s filing and agreed that Entergy Arkansas’s filing complied with the terms of the energy cost recovery rider. The redetermined rate became effective with the first billing cycle of April 2018. Subsequently in April 2018 the APSC issued an order declining to suspend Entergy Arkansas’s energy cost recovery rider rate and declining to require further investigation at that time of the issues suggested by the Attorney General in the proceeding. Following a period of discovery, the Attorney General filed a supplemental response in October 2018 raising new issues with Entergy Arkansas’s March 2018 rate redetermination and asserting that $45.7 million of the increase should be collected subject to refund pending further investigation. Also in October 2018, Entergy Arkansas filed to dismiss the Attorney General’s supplemental response, the APSC general staff filed a motion to strike the Attorney General’s filing, and the Attorney General filed its supplemental response disputing Entergy Arkansas and the APSC staff’s filing. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of the fuel adjustment clause filings by Entergy Gulf States Louisiana, whose business was combined with Entergy Louisiana in 2015. The audit includes a review of the reasonableness of charges flowed through Entergy Gulf States Louisiana’s fuel adjustment clause for the period from 2010 through 2013. Discovery commenced in July 2015. No report of audit has been issued. In May 2018 the LPSC staff provided notice of audits of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2016 through 2017. Discovery commenced in September 2018. No report of audit has been issued. 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 June 2017 the District Court issued a case management order setting a trial date in November 2018. Discovery ended in May 2018. In June 2018, Entergy filed motions for summary judgment, which are currently pending before the District Court. In July 2018 the Attorney General filed briefs opposing the summary judgment. In September 2018 the District Court held oral arguments on the Entergy companies’ motion to strike the Attorney General’s jury demand. At the hearing, the Attorney General withdrew his opposition to the Entergy companies’ motion to strike the Attorney General’s jury demand. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in an open PUCT proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. The pending appeals did not stay the PUCT’s decision, and Entergy Texas refunded to customers the $10.9 million over a four-month period beginning with the first billing cycle of July 2016. The federal appeal of the PUCT’s January 2016 decision was heard in December 2016, and the Federal District Court granted Entergy Texas’s requested relief. In January 2017 the PUCT and an intervenor filed petitions for appeal of the Federal District Court ruling to the U.S. Court of Appeals for the Fifth Circuit. Oral argument was held before the Fifth Circuit in February 2018. In April 2018 the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. In October 2018, Entergy Texas filed a notice of nonsuit in its appeal to the Travis County District Court regarding the PUCT’s January 2016 decision. In December 2017, Entergy Texas filed an application for a fuel refund of approximately $30.5 million for the months of May 2017 through October 2017. Also in December 2017, the PUCT’s ALJ approved the refund on an interim basis. For most customers, the refunds flowed through bills beginning January 2018 and continued through March 2018. The fuel refund was approved by the PUCT in March 2018. 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 information. Filings with the APSC (Entergy Arkansas) 2018 Formula Rate Plan Filing In July 2018, Entergy Arkansas filed with the APSC its 2018 formula rate plan filing to set its formula rate for the 2019 calendar year. The filing shows Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2019 test period to be below the formula rate plan bandwidth. Additionally, the filing includes the first netting adjustment under the current formula rate plan for the historical test year 2017, which is a comparison of projected costs and sales approved in the 2016 formula rate plan filing to actual 2017 costs and sales data. The filing includes a projected $73.4 million revenue deficiency for 2019 and a $95.6 million revenue deficiency for the 2017 historical test year, for a total revenue requirement of $169 million for this filing. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeds the constraint, the resulting increase is limited to four percent of total revenue, which is $65.4 million . The matter is scheduled for hearing in November 2018, and Entergy Arkansas requested that the APSC issue an order approving the proposed formula rate plan adjustment in December 2018, with the proposed formula rate plan adjustment effective with the first billing cycle of January 2019. In October 2018 the APSC staff and intervening parties filed their errors and objections to Entergy Arkansas’s 2018 formula rate plan filing, although no party proposed adjustments that would serve to reduce the requested revenue requirement below the annual revenue constraint. Entergy Arkansas also filed its rebuttal to the APSC staff and intervenors in October 2018. Later in October 2018 the parties submitted motions, which are pending with the APSC, to approve a partial settlement as to certain factual issues, to brief certain contested legal issues, and to cancel the hearing scheduled in November 2018. Similar to the 2018 filing, the formula rate plan filing that will be made in 2019 to set the formula rates for the 2020 calendar year will include a netting adjustment that will compare projected costs and sales for 2018 that were approved in the 2017 formula rate plan filing to actual 2018 costs and sales data. To the extent that Entergy Arkansas expects this netting adjustment to reflect actual 2018 revenues that are in excess of the actual costs for that year, Entergy Arkansas will record a regulatory provision in the fourth quarter 2018. Internal Restructuring As discussed in the Form 10-K, in November 2017, Entergy Arkansas filed an application with the APSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Arkansas to a new entity, which would ultimately be owned by an existing Entergy subsidiary holding company. Entergy Arkansas also filed a notice with the Missouri Public Service Commission in December 2017 out of an abundance of caution, although Entergy Arkansas does not serve any retail customers in Missouri. In April 2018 the Missouri Public Service Commission approved Entergy Arkansas’s filing. In July 2018, Entergy Arkansas filed a settlement, reached by all parties in the APSC proceeding, resolving all issues. The APSC approved the settlement agreement and restructuring in August 2018. Entergy expects to realize a permanent tax benefit at closing, and, pursuant to the settlement agreement, Entergy Arkansas will credit retail customers $39.6 million over six years, beginning in 2019. Entergy Arkansas has also received the required FERC and NRC approvals. The restructuring is anticipated to close on or before December 1, 2018. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2016 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2017, Entergy Louisiana filed its formula rate plan evaluation report for its 2016 calendar year operations. Rates reflecting the adjustments included in the formula rate plan evaluation report were implemented with the first billing cycle of September 2017, subject to refund. In September 2017 the LPSC issued its report indicating that no changes to Entergy Louisiana’s original formula rate plan evaluation report were required but reserved for several issues, including Entergy Louisiana’s September 2017 update to its formula rate plan evaluation report. In July 2018, Entergy Louisiana and the LPSC staff filed an unopposed joint report setting forth a correction to the annualization calculation, the effect of which was a net $3.5 million revenue requirement reduction, and indicating that there are no outstanding issues with the 2016 formula rate plan report, the supplemental report, or the interim updates. In September 2018 the LPSC approved the unopposed joint report. Formula Rate Plan Extension Request In August 2017, Entergy Louisiana filed a request with the LPSC seeking to extend its formula rate plan for three years (2017-2019) with limited modifications of its terms. Those modifications include: a one-time resetting of base rates to the midpoint of the band at Entergy Louisiana’s authorized return on equity of 9.95% for the 2017 test year; narrowing of the formula rate plan bandwidth from a total of 160 basis points to 80 basis points; and a forward-looking mechanism that would allow Entergy Louisiana to recover certain transmission-related costs contemporaneously with when those projects begin delivering benefits to customers. Several parties intervened in the proceeding and all parties participated in settlement discussions. In April 2018 the LPSC approved an unopposed joint motion filed by Entergy Louisiana and the LPSC staff that settles the matter. The settlement extends the formula rate plan for three years, providing for rates through at least August 2021. In addition to retaining the major features of the traditional formula rate plan, substantive features of the extended formula rate plan include: • a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation; • a 9.8% target earned return on common equity for the 2018 and 2019 test years; • narrowing of the common equity bandwidth to plus or minus 60 basis points around the target earned return on common equity; • a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity); • a framework for the flow back of certain tax benefits created by the Tax Act to customers, as described in “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above; and • a transmission recovery mechanism providing for the opportunity to recover certain transmission-related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism. 2017 Formula Rate Plan Filing In June 2018, Entergy Louisiana filed its formula rate plan evaluation report for its 2017 calendar year operations. As stated above under “Formula Rate Plan Extension Request,” for the 2017 test year there will be a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year. As such, base rider formula rate plan revenue is to be adjusted prospectively to increase or decrease the earned return on equity fully to the approved cost of equity of 9.95% . The 2017 test year evaluation report produced an earned return on equity of 8.16% , due in large part to revenue-neutral realignments to other recovery mechanisms. Without these realignments, the evaluation report produces an earned return on equity of 9.88% and a resulting base rider formula rate plan revenue increase of $4.8 million . Excluding the Tax Act credits provided for by the tax reform adjustment mechanisms, total formula rate plan revenues will further increase by a total of $98 million as a result of the evaluation report due to adjustments to the additional capacity and MISO cost recovery mechanisms of the formula rate plan, and implementation of the transmission recovery mechanism. In August 2018, Entergy Louisiana filed a supplemental formula rate plan evaluation report to reflect changes from the 2016 test year formula rate plan proceedings, a decrease to the transmission recovery mechanism to reflect lower actual capital additions, and a decrease to evaluation period expenses to reflect the terms of a new power sales agreement. Based on the August 2018 update, Entergy Louisiana would recognize a total decrease in formula rate plan revenue of approximately $17.6 million . Results of the updated 2017 evaluation report filing were implemented with the September 2018 billing month subject to refund and review by the LPSC staff and intervenors. In accordance with the terms of the formula rate plan, in September 2018 the LPSC staff and intervenors submitted their responses to Entergy Louisiana’s original formula rate plan evaluation report and supplemental compliance updates. The LPSC staff asserted objections/reservations regarding 1) Entergy Louisiana’s proposed rate adjustments associated with the return of excess accumulated deferred income taxes pursuant to the Tax Act and the treatment of accumulated deferred income taxes related to reductions of rate base; 2) Entergy Louisiana’s reservation regarding treatment of a regulatory asset related to certain special orders by the LPSC; and 3) test year expenses billed from Entergy Services to Entergy Louisiana. Intervenors also objected to Entergy Louisiana’s treatment of the regulatory asset related to certain special orders by the LPSC. A procedural schedule has not yet been established to resolve these 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. Union Power Station and Deactivation or Retirement Decisions for Entergy Louisiana Plants As discussed in the Form 10-K, as a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three-year term permitted by MISO. In March 2018 the LPSC adopted the ALJ’s recommended order finding that Entergy Louisiana did not demonstrate that its decision to permanently surrender transmission rights for the mothballed (not retired) Willow Glen 2 and 4 units was reasonable and that Entergy Louisiana should hold customers harmless from increased transmission expenses should those units be reactivated. Because no party or the LPSC suggested that Willow Glen 2 and 4 should be reactivated and because the cost to return those units to service far exceeds the revenue the units were expected to generate in MISO, Entergy Louisiana retired Willow Glen 2 and 4 in March 2018. Entergy Louisiana submitted a compliance filing regarding retirement of Willow Glen 2 and 4, and the LPSC closed the proceeding. Retail Rates - Gas 2017 Rate Stabilization Plan Filing In January 2018, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. The filing of the evaluation report for the test year 2017 reflected an earned return on common equity of 9.06% . This earned return is below the earnings sharing band of the rate stabilization plan and results in a rate increase of $0.1 million . Due to the enactment of the Tax Act in late-December 2017, Entergy Louisiana did not have adequate time to reflect the effects of this tax legislation in the rate stabilization plan. In April 2018 Entergy Louisiana filed a supplemental evaluation report for the test year ended September 2017, reflecting the effects of the Tax Act, including a proposal to use the unprotected excess accumulated deferred income taxes to offset storm restoration
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 See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements in the Form 10-K for discussion of the effects of the enactment in December 2017 of the Tax Cuts and Jobs Act (the Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. After assessing the activity described in more detail below regarding the status of the proposals the Registrant Subsidiaries made to their regulators for the return of unprotected excess accumulated deferred income taxes to customers, in 2018, Entergy and each of the Registrant Subsidiaries are reclassifying from the regulatory liability for income taxes to current liabilities the portion of their unprotected excess accumulated deferred income taxes that they expect to return to customers over the next twelve months. Entergy Arkansas See the Form 10-K for a discussion of the activity of the APSC and Entergy Arkansas after enactment of the Tax Act in December 2017. The APSC granted Entergy Arkansas’s request for clarification regarding the APSC’s order issued after enactment of the Tax Act. The APSC stated that its order was not a final determination and that the APSC had made no decision at that time on the appropriate final accounting or ratemaking treatment of the amounts in question. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its existing formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider includes a netting adjustment that compares actual annual costs and sales to the projected annual costs and sales used to establish rates. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed below, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true-up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits associated with the Tax Act. For the residential customer class, the unprotected excess accumulated deferred income taxes will be returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, the unprotected excess accumulated deferred income taxes will be returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included, with any over- or under-returned unprotected excess accumulated deferred income taxes to be credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. Entergy Louisiana See the Form 10-K for a discussion of the activity of the LPSC and Entergy Louisiana after enactment of the Tax Act in December 2017. In July 2018 the LPSC issued a proposed rule requiring utilities to adjust rates prospectively to reflect the lower tax rate (either through a formula rate plan or rate case), refund excess tax expense collected since January 1, 2018 until the lower tax rate is reflected in rates (with the refund occurring over one year), and refund excess accumulated deferred income taxes over two years. Entergy Louisiana believes that its formula rate plan settlement, approved in April 2018 and discussed below, addresses fully its obligations regarding the Tax Act and will seek such confirmation in its comments to the proposed rule. In the formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana will return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the parties agreed that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana would establish a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan are established (September 2018), and this regulatory liability will be returned to customers over the next formula rate plan rate-effective period (September 2018 through August 2019). As of September 30, 2018, Entergy Louisiana has a $67 million regulatory liability recorded pursuant to this provision of the settlement. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing, which, as discussed below, Entergy Louisiana filed in June 2018. Entergy Mississippi As discussed in the Form 10-K, after enactment of the Tax Act the MPSC ordered utilities, including Entergy Mississippi, that operate under a formula rate plan to file a description by February 26, 2018, of how the Tax Act will be reflected in the formula rate plan under which the utility operates. Entergy Mississippi's plan, as filed with the MPSC on February 26, 2018, included a request to reflect the changes related to the Tax Act in the 2018 formula rate plan filing. Entergy Mississippi filed its 2018 formula rate plan on March 15, 2018 and included a proposal to return all of its unprotected excess accumulated deferred income taxes to customers through rates or in exchange for other assets, or a combination of both, by the end of 2018. Also, in March 2018 the MPSC issued a subsequent order in its generic tax reform docket ordering utilities, including Entergy Mississippi, to explain the implementation of the utilities tax adjustment clause, or, in the alternative, why the tax adjustment clause is inapplicable; submit an analysis of the ratemaking effects of the Tax Act on current and future revenue requirements for rate schedules that include a gross-up for federal taxes; and make appropriate accounting entries to recognize the removal of excess deferred taxes from the balance of the utility’s accumulated deferred income tax account, or, in the alternative, explain why recording such entries is not appropriate. In April 2018, Entergy Mississippi filed its response to the MPSC stating that the tax adjustment clauses in its base rates are properly implemented through its formula rate plan. Entergy Mississippi also provided analysis of the ratemaking effects of the Tax Act. In June 2018, Entergy Mississippi and the Mississippi Public Utilities Staff entered into and filed a joint stipulation in Entergy Mississippi’s formula rate plan filing that addressed Entergy Mississippi’s 2018 formula rate plan evaluation report and the ratemaking effects of the Tax Act. Also in June 2018 the MPSC approved the stipulation, which provides for incorporating the reduction of the statutory federal income tax rate through the formula rate plan. Entergy Mississippi’s formula rate plan includes a look-back evaluation report filing in March 2019 that will compare actual 2018 results to the allowed return on rate base. The stipulation provides for the flow-back of protected excess accumulated deferred income taxes over approximately 40 years through the formula rate plan. The stipulation also provides for the offset of unprotected excess accumulated deferred income taxes of $127.2 million against net utility plant and $2.2 million against other regulatory assets, and the return to customers of the remaining balance of unprotected excess accumulated deferred income taxes as recovery of a portion of fuel oil inventory and customer bill credits over a three-month period from July 2018 through September 2018, with any true-up to be reflected in the November 2018 power management rider submittal. Entergy Mississippi recorded the reduction against net utility plant and other regulatory assets in June 2018. In third quarter 2018, Entergy Mississippi returned unprotected excess accumulated deferred income taxes of $25.8 million through customer bill credits and $5.8 million through the sale of fuel oil inventory. Entergy New Orleans As discussed in the Form 10-K, after enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy has submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what is presently reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits starting in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at FERC. The agreement in principle was approved by the City Council in June 2018. Entergy Texas As discussed below, in May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflect the inclusion of the federal income tax reductions due to the Tax Act. See the discussion below regarding the terms of an unopposed settlement submitted by the parties to the 2018 rate case that, if approved by the PUCT, establishes the amounts and timing of the return of protected and unprotected excess accumulated deferred income taxes to Entergy Texas customers. 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 are ongoing. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2018, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01547 per kWh to $0.01882 per kWh. The Arkansas Attorney General filed a response to Entergy Arkansas’s annual redetermination filing requesting that the APSC suspend the proposed tariff to investigate the amount of the redetermination or, alternatively, to allow recovery subject to refund. Among the reasons the Attorney General cited for suspension were questions pertaining to how Entergy Arkansas forecasted sales and potential implications of the Tax Act. Entergy Arkansas replied to the Attorney General’s filing and stated that, to the extent there are questions pertaining to its load forecasting or the operation of the energy cost recovery rider, those issues exceed the scope of the instant rate redetermination. Entergy Arkansas also stated that potential effects of the Tax Act are appropriately considered in the APSC’s separate proceeding looking at potential implications of the new tax law. The APSC general staff filed a reply to the Attorney General’s filing and agreed that Entergy Arkansas’s filing complied with the terms of the energy cost recovery rider. The redetermined rate became effective with the first billing cycle of April 2018. Subsequently in April 2018 the APSC issued an order declining to suspend Entergy Arkansas’s energy cost recovery rider rate and declining to require further investigation at that time of the issues suggested by the Attorney General in the proceeding. Following a period of discovery, the Attorney General filed a supplemental response in October 2018 raising new issues with Entergy Arkansas’s March 2018 rate redetermination and asserting that $45.7 million of the increase should be collected subject to refund pending further investigation. Also in October 2018, Entergy Arkansas filed to dismiss the Attorney General’s supplemental response, the APSC general staff filed a motion to strike the Attorney General’s filing, and the Attorney General filed its supplemental response disputing Entergy Arkansas and the APSC staff’s filing. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of the fuel adjustment clause filings by Entergy Gulf States Louisiana, whose business was combined with Entergy Louisiana in 2015. The audit includes a review of the reasonableness of charges flowed through Entergy Gulf States Louisiana’s fuel adjustment clause for the period from 2010 through 2013. Discovery commenced in July 2015. No report of audit has been issued. In May 2018 the LPSC staff provided notice of audits of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2016 through 2017. Discovery commenced in September 2018. No report of audit has been issued. 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 June 2017 the District Court issued a case management order setting a trial date in November 2018. Discovery ended in May 2018. In June 2018, Entergy filed motions for summary judgment, which are currently pending before the District Court. In July 2018 the Attorney General filed briefs opposing the summary judgment. In September 2018 the District Court held oral arguments on the Entergy companies’ motion to strike the Attorney General’s jury demand. At the hearing, the Attorney General withdrew his opposition to the Entergy companies’ motion to strike the Attorney General’s jury demand. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in an open PUCT proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. The pending appeals did not stay the PUCT’s decision, and Entergy Texas refunded to customers the $10.9 million over a four-month period beginning with the first billing cycle of July 2016. The federal appeal of the PUCT’s January 2016 decision was heard in December 2016, and the Federal District Court granted Entergy Texas’s requested relief. In January 2017 the PUCT and an intervenor filed petitions for appeal of the Federal District Court ruling to the U.S. Court of Appeals for the Fifth Circuit. Oral argument was held before the Fifth Circuit in February 2018. In April 2018 the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. In October 2018, Entergy Texas filed a notice of nonsuit in its appeal to the Travis County District Court regarding the PUCT’s January 2016 decision. In December 2017, Entergy Texas filed an application for a fuel refund of approximately $30.5 million for the months of May 2017 through October 2017. Also in December 2017, the PUCT’s ALJ approved the refund on an interim basis. For most customers, the refunds flowed through bills beginning January 2018 and continued through March 2018. The fuel refund was approved by the PUCT in March 2018. 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 information. Filings with the APSC (Entergy Arkansas) 2018 Formula Rate Plan Filing In July 2018, Entergy Arkansas filed with the APSC its 2018 formula rate plan filing to set its formula rate for the 2019 calendar year. The filing shows Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2019 test period to be below the formula rate plan bandwidth. Additionally, the filing includes the first netting adjustment under the current formula rate plan for the historical test year 2017, which is a comparison of projected costs and sales approved in the 2016 formula rate plan filing to actual 2017 costs and sales data. The filing includes a projected $73.4 million revenue deficiency for 2019 and a $95.6 million revenue deficiency for the 2017 historical test year, for a total revenue requirement of $169 million for this filing. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeds the constraint, the resulting increase is limited to four percent of total revenue, which is $65.4 million . The matter is scheduled for hearing in November 2018, and Entergy Arkansas requested that the APSC issue an order approving the proposed formula rate plan adjustment in December 2018, with the proposed formula rate plan adjustment effective with the first billing cycle of January 2019. In October 2018 the APSC staff and intervening parties filed their errors and objections to Entergy Arkansas’s 2018 formula rate plan filing, although no party proposed adjustments that would serve to reduce the requested revenue requirement below the annual revenue constraint. Entergy Arkansas also filed its rebuttal to the APSC staff and intervenors in October 2018. Later in October 2018 the parties submitted motions, which are pending with the APSC, to approve a partial settlement as to certain factual issues, to brief certain contested legal issues, and to cancel the hearing scheduled in November 2018. Similar to the 2018 filing, the formula rate plan filing that will be made in 2019 to set the formula rates for the 2020 calendar year will include a netting adjustment that will compare projected costs and sales for 2018 that were approved in the 2017 formula rate plan filing to actual 2018 costs and sales data. To the extent that Entergy Arkansas expects this netting adjustment to reflect actual 2018 revenues that are in excess of the actual costs for that year, Entergy Arkansas will record a regulatory provision in the fourth quarter 2018. Internal Restructuring As discussed in the Form 10-K, in November 2017, Entergy Arkansas filed an application with the APSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Arkansas to a new entity, which would ultimately be owned by an existing Entergy subsidiary holding company. Entergy Arkansas also filed a notice with the Missouri Public Service Commission in December 2017 out of an abundance of caution, although Entergy Arkansas does not serve any retail customers in Missouri. In April 2018 the Missouri Public Service Commission approved Entergy Arkansas’s filing. In July 2018, Entergy Arkansas filed a settlement, reached by all parties in the APSC proceeding, resolving all issues. The APSC approved the settlement agreement and restructuring in August 2018. Entergy expects to realize a permanent tax benefit at closing, and, pursuant to the settlement agreement, Entergy Arkansas will credit retail customers $39.6 million over six years, beginning in 2019. Entergy Arkansas has also received the required FERC and NRC approvals. The restructuring is anticipated to close on or before December 1, 2018. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2016 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2017, Entergy Louisiana filed its formula rate plan evaluation report for its 2016 calendar year operations. Rates reflecting the adjustments included in the formula rate plan evaluation report were implemented with the first billing cycle of September 2017, subject to refund. In September 2017 the LPSC issued its report indicating that no changes to Entergy Louisiana’s original formula rate plan evaluation report were required but reserved for several issues, including Entergy Louisiana’s September 2017 update to its formula rate plan evaluation report. In July 2018, Entergy Louisiana and the LPSC staff filed an unopposed joint report setting forth a correction to the annualization calculation, the effect of which was a net $3.5 million revenue requirement reduction, and indicating that there are no outstanding issues with the 2016 formula rate plan report, the supplemental report, or the interim updates. In September 2018 the LPSC approved the unopposed joint report. Formula Rate Plan Extension Request In August 2017, Entergy Louisiana filed a request with the LPSC seeking to extend its formula rate plan for three years (2017-2019) with limited modifications of its terms. Those modifications include: a one-time resetting of base rates to the midpoint of the band at Entergy Louisiana’s authorized return on equity of 9.95% for the 2017 test year; narrowing of the formula rate plan bandwidth from a total of 160 basis points to 80 basis points; and a forward-looking mechanism that would allow Entergy Louisiana to recover certain transmission-related costs contemporaneously with when those projects begin delivering benefits to customers. Several parties intervened in the proceeding and all parties participated in settlement discussions. In April 2018 the LPSC approved an unopposed joint motion filed by Entergy Louisiana and the LPSC staff that settles the matter. The settlement extends the formula rate plan for three years, providing for rates through at least August 2021. In addition to retaining the major features of the traditional formula rate plan, substantive features of the extended formula rate plan include: • a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation; • a 9.8% target earned return on common equity for the 2018 and 2019 test years; • narrowing of the common equity bandwidth to plus or minus 60 basis points around the target earned return on common equity; • a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity); • a framework for the flow back of certain tax benefits created by the Tax Act to customers, as described in “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above; and • a transmission recovery mechanism providing for the opportunity to recover certain transmission-related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism. 2017 Formula Rate Plan Filing In June 2018, Entergy Louisiana filed its formula rate plan evaluation report for its 2017 calendar year operations. As stated above under “Formula Rate Plan Extension Request,” for the 2017 test year there will be a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year. As such, base rider formula rate plan revenue is to be adjusted prospectively to increase or decrease the earned return on equity fully to the approved cost of equity of 9.95% . The 2017 test year evaluation report produced an earned return on equity of 8.16% , due in large part to revenue-neutral realignments to other recovery mechanisms. Without these realignments, the evaluation report produces an earned return on equity of 9.88% and a resulting base rider formula rate plan revenue increase of $4.8 million . Excluding the Tax Act credits provided for by the tax reform adjustment mechanisms, total formula rate plan revenues will further increase by a total of $98 million as a result of the evaluation report due to adjustments to the additional capacity and MISO cost recovery mechanisms of the formula rate plan, and implementation of the transmission recovery mechanism. In August 2018, Entergy Louisiana filed a supplemental formula rate plan evaluation report to reflect changes from the 2016 test year formula rate plan proceedings, a decrease to the transmission recovery mechanism to reflect lower actual capital additions, and a decrease to evaluation period expenses to reflect the terms of a new power sales agreement. Based on the August 2018 update, Entergy Louisiana would recognize a total decrease in formula rate plan revenue of approximately $17.6 million . Results of the updated 2017 evaluation report filing were implemented with the September 2018 billing month subject to refund and review by the LPSC staff and intervenors. In accordance with the terms of the formula rate plan, in September 2018 the LPSC staff and intervenors submitted their responses to Entergy Louisiana’s original formula rate plan evaluation report and supplemental compliance updates. The LPSC staff asserted objections/reservations regarding 1) Entergy Louisiana’s proposed rate adjustments associated with the return of excess accumulated deferred income taxes pursuant to the Tax Act and the treatment of accumulated deferred income taxes related to reductions of rate base; 2) Entergy Louisiana’s reservation regarding treatment of a regulatory asset related to certain special orders by the LPSC; and 3) test year expenses billed from Entergy Services to Entergy Louisiana. Intervenors also objected to Entergy Louisiana’s treatment of the regulatory asset related to certain special orders by the LPSC. A procedural schedule has not yet been established to resolve these 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. Union Power Station and Deactivation or Retirement Decisions for Entergy Louisiana Plants As discussed in the Form 10-K, as a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three-year term permitted by MISO. In March 2018 the LPSC adopted the ALJ’s recommended order finding that Entergy Louisiana did not demonstrate that its decision to permanently surrender transmission rights for the mothballed (not retired) Willow Glen 2 and 4 units was reasonable and that Entergy Louisiana should hold customers harmless from increased transmission expenses should those units be reactivated. Because no party or the LPSC suggested that Willow Glen 2 and 4 should be reactivated and because the cost to return those units to service far exceeds the revenue the units were expected to generate in MISO, Entergy Louisiana retired Willow Glen 2 and 4 in March 2018. Entergy Louisiana submitted a compliance filing regarding retirement of Willow Glen 2 and 4, and the LPSC closed the proceeding. Retail Rates - Gas 2017 Rate Stabilization Plan Filing In January 2018, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. The filing of the evaluation report for the test year 2017 reflected an earned return on common equity of 9.06% . This earned return is below the earnings sharing band of the rate stabilization plan and results in a rate increase of $0.1 million . Due to the enactment of the Tax Act in late-December 2017, Entergy Louisiana did not have adequate time to reflect the effects of this tax legislation in the rate stabilization plan. In April 2018 Entergy Louisiana filed a supplemental evaluation report for the test year ended September 2017, reflecting the effects of the Tax Act, including a proposal to use the unprotected excess accumulated deferred income taxes to offset storm restoration
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 See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements in the Form 10-K for discussion of the effects of the enactment in December 2017 of the Tax Cuts and Jobs Act (the Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. After assessing the activity described in more detail below regarding the status of the proposals the Registrant Subsidiaries made to their regulators for the return of unprotected excess accumulated deferred income taxes to customers, in 2018, Entergy and each of the Registrant Subsidiaries are reclassifying from the regulatory liability for income taxes to current liabilities the portion of their unprotected excess accumulated deferred income taxes that they expect to return to customers over the next twelve months. Entergy Arkansas See the Form 10-K for a discussion of the activity of the APSC and Entergy Arkansas after enactment of the Tax Act in December 2017. The APSC granted Entergy Arkansas’s request for clarification regarding the APSC’s order issued after enactment of the Tax Act. The APSC stated that its order was not a final determination and that the APSC had made no decision at that time on the appropriate final accounting or ratemaking treatment of the amounts in question. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its existing formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider includes a netting adjustment that compares actual annual costs and sales to the projected annual costs and sales used to establish rates. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed below, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true-up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits associated with the Tax Act. For the residential customer class, the unprotected excess accumulated deferred income taxes will be returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, the unprotected excess accumulated deferred income taxes will be returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included, with any over- or under-returned unprotected excess accumulated deferred income taxes to be credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. Entergy Louisiana See the Form 10-K for a discussion of the activity of the LPSC and Entergy Louisiana after enactment of the Tax Act in December 2017. In July 2018 the LPSC issued a proposed rule requiring utilities to adjust rates prospectively to reflect the lower tax rate (either through a formula rate plan or rate case), refund excess tax expense collected since January 1, 2018 until the lower tax rate is reflected in rates (with the refund occurring over one year), and refund excess accumulated deferred income taxes over two years. Entergy Louisiana believes that its formula rate plan settlement, approved in April 2018 and discussed below, addresses fully its obligations regarding the Tax Act and will seek such confirmation in its comments to the proposed rule. In the formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana will return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the parties agreed that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana would establish a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan are established (September 2018), and this regulatory liability will be returned to customers over the next formula rate plan rate-effective period (September 2018 through August 2019). As of September 30, 2018, Entergy Louisiana has a $67 million regulatory liability recorded pursuant to this provision of the settlement. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing, which, as discussed below, Entergy Louisiana filed in June 2018. Entergy Mississippi As discussed in the Form 10-K, after enactment of the Tax Act the MPSC ordered utilities, including Entergy Mississippi, that operate under a formula rate plan to file a description by February 26, 2018, of how the Tax Act will be reflected in the formula rate plan under which the utility operates. Entergy Mississippi's plan, as filed with the MPSC on February 26, 2018, included a request to reflect the changes related to the Tax Act in the 2018 formula rate plan filing. Entergy Mississippi filed its 2018 formula rate plan on March 15, 2018 and included a proposal to return all of its unprotected excess accumulated deferred income taxes to customers through rates or in exchange for other assets, or a combination of both, by the end of 2018. Also, in March 2018 the MPSC issued a subsequent order in its generic tax reform docket ordering utilities, including Entergy Mississippi, to explain the implementation of the utilities tax adjustment clause, or, in the alternative, why the tax adjustment clause is inapplicable; submit an analysis of the ratemaking effects of the Tax Act on current and future revenue requirements for rate schedules that include a gross-up for federal taxes; and make appropriate accounting entries to recognize the removal of excess deferred taxes from the balance of the utility’s accumulated deferred income tax account, or, in the alternative, explain why recording such entries is not appropriate. In April 2018, Entergy Mississippi filed its response to the MPSC stating that the tax adjustment clauses in its base rates are properly implemented through its formula rate plan. Entergy Mississippi also provided analysis of the ratemaking effects of the Tax Act. In June 2018, Entergy Mississippi and the Mississippi Public Utilities Staff entered into and filed a joint stipulation in Entergy Mississippi’s formula rate plan filing that addressed Entergy Mississippi’s 2018 formula rate plan evaluation report and the ratemaking effects of the Tax Act. Also in June 2018 the MPSC approved the stipulation, which provides for incorporating the reduction of the statutory federal income tax rate through the formula rate plan. Entergy Mississippi’s formula rate plan includes a look-back evaluation report filing in March 2019 that will compare actual 2018 results to the allowed return on rate base. The stipulation provides for the flow-back of protected excess accumulated deferred income taxes over approximately 40 years through the formula rate plan. The stipulation also provides for the offset of unprotected excess accumulated deferred income taxes of $127.2 million against net utility plant and $2.2 million against other regulatory assets, and the return to customers of the remaining balance of unprotected excess accumulated deferred income taxes as recovery of a portion of fuel oil inventory and customer bill credits over a three-month period from July 2018 through September 2018, with any true-up to be reflected in the November 2018 power management rider submittal. Entergy Mississippi recorded the reduction against net utility plant and other regulatory assets in June 2018. In third quarter 2018, Entergy Mississippi returned unprotected excess accumulated deferred income taxes of $25.8 million through customer bill credits and $5.8 million through the sale of fuel oil inventory. Entergy New Orleans As discussed in the Form 10-K, after enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy has submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what is presently reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits starting in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at FERC. The agreement in principle was approved by the City Council in June 2018. Entergy Texas As discussed below, in May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflect the inclusion of the federal income tax reductions due to the Tax Act. See the discussion below regarding the terms of an unopposed settlement submitted by the parties to the 2018 rate case that, if approved by the PUCT, establishes the amounts and timing of the return of protected and unprotected excess accumulated deferred income taxes to Entergy Texas customers. 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 are ongoing. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2018, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01547 per kWh to $0.01882 per kWh. The Arkansas Attorney General filed a response to Entergy Arkansas’s annual redetermination filing requesting that the APSC suspend the proposed tariff to investigate the amount of the redetermination or, alternatively, to allow recovery subject to refund. Among the reasons the Attorney General cited for suspension were questions pertaining to how Entergy Arkansas forecasted sales and potential implications of the Tax Act. Entergy Arkansas replied to the Attorney General’s filing and stated that, to the extent there are questions pertaining to its load forecasting or the operation of the energy cost recovery rider, those issues exceed the scope of the instant rate redetermination. Entergy Arkansas also stated that potential effects of the Tax Act are appropriately considered in the APSC’s separate proceeding looking at potential implications of the new tax law. The APSC general staff filed a reply to the Attorney General’s filing and agreed that Entergy Arkansas’s filing complied with the terms of the energy cost recovery rider. The redetermined rate became effective with the first billing cycle of April 2018. Subsequently in April 2018 the APSC issued an order declining to suspend Entergy Arkansas’s energy cost recovery rider rate and declining to require further investigation at that time of the issues suggested by the Attorney General in the proceeding. Following a period of discovery, the Attorney General filed a supplemental response in October 2018 raising new issues with Entergy Arkansas’s March 2018 rate redetermination and asserting that $45.7 million of the increase should be collected subject to refund pending further investigation. Also in October 2018, Entergy Arkansas filed to dismiss the Attorney General’s supplemental response, the APSC general staff filed a motion to strike the Attorney General’s filing, and the Attorney General filed its supplemental response disputing Entergy Arkansas and the APSC staff’s filing. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of the fuel adjustment clause filings by Entergy Gulf States Louisiana, whose business was combined with Entergy Louisiana in 2015. The audit includes a review of the reasonableness of charges flowed through Entergy Gulf States Louisiana’s fuel adjustment clause for the period from 2010 through 2013. Discovery commenced in July 2015. No report of audit has been issued. In May 2018 the LPSC staff provided notice of audits of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2016 through 2017. Discovery commenced in September 2018. No report of audit has been issued. 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 June 2017 the District Court issued a case management order setting a trial date in November 2018. Discovery ended in May 2018. In June 2018, Entergy filed motions for summary judgment, which are currently pending before the District Court. In July 2018 the Attorney General filed briefs opposing the summary judgment. In September 2018 the District Court held oral arguments on the Entergy companies’ motion to strike the Attorney General’s jury demand. At the hearing, the Attorney General withdrew his opposition to the Entergy companies’ motion to strike the Attorney General’s jury demand. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in an open PUCT proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. The pending appeals did not stay the PUCT’s decision, and Entergy Texas refunded to customers the $10.9 million over a four-month period beginning with the first billing cycle of July 2016. The federal appeal of the PUCT’s January 2016 decision was heard in December 2016, and the Federal District Court granted Entergy Texas’s requested relief. In January 2017 the PUCT and an intervenor filed petitions for appeal of the Federal District Court ruling to the U.S. Court of Appeals for the Fifth Circuit. Oral argument was held before the Fifth Circuit in February 2018. In April 2018 the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. In October 2018, Entergy Texas filed a notice of nonsuit in its appeal to the Travis County District Court regarding the PUCT’s January 2016 decision. In December 2017, Entergy Texas filed an application for a fuel refund of approximately $30.5 million for the months of May 2017 through October 2017. Also in December 2017, the PUCT’s ALJ approved the refund on an interim basis. For most customers, the refunds flowed through bills beginning January 2018 and continued through March 2018. The fuel refund was approved by the PUCT in March 2018. 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 information. Filings with the APSC (Entergy Arkansas) 2018 Formula Rate Plan Filing In July 2018, Entergy Arkansas filed with the APSC its 2018 formula rate plan filing to set its formula rate for the 2019 calendar year. The filing shows Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2019 test period to be below the formula rate plan bandwidth. Additionally, the filing includes the first netting adjustment under the current formula rate plan for the historical test year 2017, which is a comparison of projected costs and sales approved in the 2016 formula rate plan filing to actual 2017 costs and sales data. The filing includes a projected $73.4 million revenue deficiency for 2019 and a $95.6 million revenue deficiency for the 2017 historical test year, for a total revenue requirement of $169 million for this filing. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeds the constraint, the resulting increase is limited to four percent of total revenue, which is $65.4 million . The matter is scheduled for hearing in November 2018, and Entergy Arkansas requested that the APSC issue an order approving the proposed formula rate plan adjustment in December 2018, with the proposed formula rate plan adjustment effective with the first billing cycle of January 2019. In October 2018 the APSC staff and intervening parties filed their errors and objections to Entergy Arkansas’s 2018 formula rate plan filing, although no party proposed adjustments that would serve to reduce the requested revenue requirement below the annual revenue constraint. Entergy Arkansas also filed its rebuttal to the APSC staff and intervenors in October 2018. Later in October 2018 the parties submitted motions, which are pending with the APSC, to approve a partial settlement as to certain factual issues, to brief certain contested legal issues, and to cancel the hearing scheduled in November 2018. Similar to the 2018 filing, the formula rate plan filing that will be made in 2019 to set the formula rates for the 2020 calendar year will include a netting adjustment that will compare projected costs and sales for 2018 that were approved in the 2017 formula rate plan filing to actual 2018 costs and sales data. To the extent that Entergy Arkansas expects this netting adjustment to reflect actual 2018 revenues that are in excess of the actual costs for that year, Entergy Arkansas will record a regulatory provision in the fourth quarter 2018. Internal Restructuring As discussed in the Form 10-K, in November 2017, Entergy Arkansas filed an application with the APSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Arkansas to a new entity, which would ultimately be owned by an existing Entergy subsidiary holding company. Entergy Arkansas also filed a notice with the Missouri Public Service Commission in December 2017 out of an abundance of caution, although Entergy Arkansas does not serve any retail customers in Missouri. In April 2018 the Missouri Public Service Commission approved Entergy Arkansas’s filing. In July 2018, Entergy Arkansas filed a settlement, reached by all parties in the APSC proceeding, resolving all issues. The APSC approved the settlement agreement and restructuring in August 2018. Entergy expects to realize a permanent tax benefit at closing, and, pursuant to the settlement agreement, Entergy Arkansas will credit retail customers $39.6 million over six years, beginning in 2019. Entergy Arkansas has also received the required FERC and NRC approvals. The restructuring is anticipated to close on or before December 1, 2018. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2016 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2017, Entergy Louisiana filed its formula rate plan evaluation report for its 2016 calendar year operations. Rates reflecting the adjustments included in the formula rate plan evaluation report were implemented with the first billing cycle of September 2017, subject to refund. In September 2017 the LPSC issued its report indicating that no changes to Entergy Louisiana’s original formula rate plan evaluation report were required but reserved for several issues, including Entergy Louisiana’s September 2017 update to its formula rate plan evaluation report. In July 2018, Entergy Louisiana and the LPSC staff filed an unopposed joint report setting forth a correction to the annualization calculation, the effect of which was a net $3.5 million revenue requirement reduction, and indicating that there are no outstanding issues with the 2016 formula rate plan report, the supplemental report, or the interim updates. In September 2018 the LPSC approved the unopposed joint report. Formula Rate Plan Extension Request In August 2017, Entergy Louisiana filed a request with the LPSC seeking to extend its formula rate plan for three years (2017-2019) with limited modifications of its terms. Those modifications include: a one-time resetting of base rates to the midpoint of the band at Entergy Louisiana’s authorized return on equity of 9.95% for the 2017 test year; narrowing of the formula rate plan bandwidth from a total of 160 basis points to 80 basis points; and a forward-looking mechanism that would allow Entergy Louisiana to recover certain transmission-related costs contemporaneously with when those projects begin delivering benefits to customers. Several parties intervened in the proceeding and all parties participated in settlement discussions. In April 2018 the LPSC approved an unopposed joint motion filed by Entergy Louisiana and the LPSC staff that settles the matter. The settlement extends the formula rate plan for three years, providing for rates through at least August 2021. In addition to retaining the major features of the traditional formula rate plan, substantive features of the extended formula rate plan include: • a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation; • a 9.8% target earned return on common equity for the 2018 and 2019 test years; • narrowing of the common equity bandwidth to plus or minus 60 basis points around the target earned return on common equity; • a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity); • a framework for the flow back of certain tax benefits created by the Tax Act to customers, as described in “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above; and • a transmission recovery mechanism providing for the opportunity to recover certain transmission-related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism. 2017 Formula Rate Plan Filing In June 2018, Entergy Louisiana filed its formula rate plan evaluation report for its 2017 calendar year operations. As stated above under “Formula Rate Plan Extension Request,” for the 2017 test year there will be a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year. As such, base rider formula rate plan revenue is to be adjusted prospectively to increase or decrease the earned return on equity fully to the approved cost of equity of 9.95% . The 2017 test year evaluation report produced an earned return on equity of 8.16% , due in large part to revenue-neutral realignments to other recovery mechanisms. Without these realignments, the evaluation report produces an earned return on equity of 9.88% and a resulting base rider formula rate plan revenue increase of $4.8 million . Excluding the Tax Act credits provided for by the tax reform adjustment mechanisms, total formula rate plan revenues will further increase by a total of $98 million as a result of the evaluation report due to adjustments to the additional capacity and MISO cost recovery mechanisms of the formula rate plan, and implementation of the transmission recovery mechanism. In August 2018, Entergy Louisiana filed a supplemental formula rate plan evaluation report to reflect changes from the 2016 test year formula rate plan proceedings, a decrease to the transmission recovery mechanism to reflect lower actual capital additions, and a decrease to evaluation period expenses to reflect the terms of a new power sales agreement. Based on the August 2018 update, Entergy Louisiana would recognize a total decrease in formula rate plan revenue of approximately $17.6 million . Results of the updated 2017 evaluation report filing were implemented with the September 2018 billing month subject to refund and review by the LPSC staff and intervenors. In accordance with the terms of the formula rate plan, in September 2018 the LPSC staff and intervenors submitted their responses to Entergy Louisiana’s original formula rate plan evaluation report and supplemental compliance updates. The LPSC staff asserted objections/reservations regarding 1) Entergy Louisiana’s proposed rate adjustments associated with the return of excess accumulated deferred income taxes pursuant to the Tax Act and the treatment of accumulated deferred income taxes related to reductions of rate base; 2) Entergy Louisiana’s reservation regarding treatment of a regulatory asset related to certain special orders by the LPSC; and 3) test year expenses billed from Entergy Services to Entergy Louisiana. Intervenors also objected to Entergy Louisiana’s treatment of the regulatory asset related to certain special orders by the LPSC. A procedural schedule has not yet been established to resolve these 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. Union Power Station and Deactivation or Retirement Decisions for Entergy Louisiana Plants As discussed in the Form 10-K, as a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three-year term permitted by MISO. In March 2018 the LPSC adopted the ALJ’s recommended order finding that Entergy Louisiana did not demonstrate that its decision to permanently surrender transmission rights for the mothballed (not retired) Willow Glen 2 and 4 units was reasonable and that Entergy Louisiana should hold customers harmless from increased transmission expenses should those units be reactivated. Because no party or the LPSC suggested that Willow Glen 2 and 4 should be reactivated and because the cost to return those units to service far exceeds the revenue the units were expected to generate in MISO, Entergy Louisiana retired Willow Glen 2 and 4 in March 2018. Entergy Louisiana submitted a compliance filing regarding retirement of Willow Glen 2 and 4, and the LPSC closed the proceeding. Retail Rates - Gas 2017 Rate Stabilization Plan Filing In January 2018, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. The filing of the evaluation report for the test year 2017 reflected an earned return on common equity of 9.06% . This earned return is below the earnings sharing band of the rate stabilization plan and results in a rate increase of $0.1 million . Due to the enactment of the Tax Act in late-December 2017, Entergy Louisiana did not have adequate time to reflect the effects of this tax legislation in the rate stabilization plan. In April 2018 Entergy Louisiana filed a supplemental evaluation report for the test year ended September 2017, reflecting the effects of the Tax Act, including a proposal to use the unprotected excess accumulated deferred income taxes to offset storm restoration
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 See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements in the Form 10-K for discussion of the effects of the enactment in December 2017 of the Tax Cuts and Jobs Act (the Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. After assessing the activity described in more detail below regarding the status of the proposals the Registrant Subsidiaries made to their regulators for the return of unprotected excess accumulated deferred income taxes to customers, in 2018, Entergy and each of the Registrant Subsidiaries are reclassifying from the regulatory liability for income taxes to current liabilities the portion of their unprotected excess accumulated deferred income taxes that they expect to return to customers over the next twelve months. Entergy Arkansas See the Form 10-K for a discussion of the activity of the APSC and Entergy Arkansas after enactment of the Tax Act in December 2017. The APSC granted Entergy Arkansas’s request for clarification regarding the APSC’s order issued after enactment of the Tax Act. The APSC stated that its order was not a final determination and that the APSC had made no decision at that time on the appropriate final accounting or ratemaking treatment of the amounts in question. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its existing formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider includes a netting adjustment that compares actual annual costs and sales to the projected annual costs and sales used to establish rates. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed below, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true-up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits associated with the Tax Act. For the residential customer class, the unprotected excess accumulated deferred income taxes will be returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, the unprotected excess accumulated deferred income taxes will be returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included, with any over- or under-returned unprotected excess accumulated deferred income taxes to be credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. Entergy Louisiana See the Form 10-K for a discussion of the activity of the LPSC and Entergy Louisiana after enactment of the Tax Act in December 2017. In July 2018 the LPSC issued a proposed rule requiring utilities to adjust rates prospectively to reflect the lower tax rate (either through a formula rate plan or rate case), refund excess tax expense collected since January 1, 2018 until the lower tax rate is reflected in rates (with the refund occurring over one year), and refund excess accumulated deferred income taxes over two years. Entergy Louisiana believes that its formula rate plan settlement, approved in April 2018 and discussed below, addresses fully its obligations regarding the Tax Act and will seek such confirmation in its comments to the proposed rule. In the formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana will return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the parties agreed that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana would establish a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan are established (September 2018), and this regulatory liability will be returned to customers over the next formula rate plan rate-effective period (September 2018 through August 2019). As of September 30, 2018, Entergy Louisiana has a $67 million regulatory liability recorded pursuant to this provision of the settlement. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing, which, as discussed below, Entergy Louisiana filed in June 2018. Entergy Mississippi As discussed in the Form 10-K, after enactment of the Tax Act the MPSC ordered utilities, including Entergy Mississippi, that operate under a formula rate plan to file a description by February 26, 2018, of how the Tax Act will be reflected in the formula rate plan under which the utility operates. Entergy Mississippi's plan, as filed with the MPSC on February 26, 2018, included a request to reflect the changes related to the Tax Act in the 2018 formula rate plan filing. Entergy Mississippi filed its 2018 formula rate plan on March 15, 2018 and included a proposal to return all of its unprotected excess accumulated deferred income taxes to customers through rates or in exchange for other assets, or a combination of both, by the end of 2018. Also, in March 2018 the MPSC issued a subsequent order in its generic tax reform docket ordering utilities, including Entergy Mississippi, to explain the implementation of the utilities tax adjustment clause, or, in the alternative, why the tax adjustment clause is inapplicable; submit an analysis of the ratemaking effects of the Tax Act on current and future revenue requirements for rate schedules that include a gross-up for federal taxes; and make appropriate accounting entries to recognize the removal of excess deferred taxes from the balance of the utility’s accumulated deferred income tax account, or, in the alternative, explain why recording such entries is not appropriate. In April 2018, Entergy Mississippi filed its response to the MPSC stating that the tax adjustment clauses in its base rates are properly implemented through its formula rate plan. Entergy Mississippi also provided analysis of the ratemaking effects of the Tax Act. In June 2018, Entergy Mississippi and the Mississippi Public Utilities Staff entered into and filed a joint stipulation in Entergy Mississippi’s formula rate plan filing that addressed Entergy Mississippi’s 2018 formula rate plan evaluation report and the ratemaking effects of the Tax Act. Also in June 2018 the MPSC approved the stipulation, which provides for incorporating the reduction of the statutory federal income tax rate through the formula rate plan. Entergy Mississippi’s formula rate plan includes a look-back evaluation report filing in March 2019 that will compare actual 2018 results to the allowed return on rate base. The stipulation provides for the flow-back of protected excess accumulated deferred income taxes over approximately 40 years through the formula rate plan. The stipulation also provides for the offset of unprotected excess accumulated deferred income taxes of $127.2 million against net utility plant and $2.2 million against other regulatory assets, and the return to customers of the remaining balance of unprotected excess accumulated deferred income taxes as recovery of a portion of fuel oil inventory and customer bill credits over a three-month period from July 2018 through September 2018, with any true-up to be reflected in the November 2018 power management rider submittal. Entergy Mississippi recorded the reduction against net utility plant and other regulatory assets in June 2018. In third quarter 2018, Entergy Mississippi returned unprotected excess accumulated deferred income taxes of $25.8 million through customer bill credits and $5.8 million through the sale of fuel oil inventory. Entergy New Orleans As discussed in the Form 10-K, after enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy has submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what is presently reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits starting in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at FERC. The agreement in principle was approved by the City Council in June 2018. Entergy Texas As discussed below, in May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflect the inclusion of the federal income tax reductions due to the Tax Act. See the discussion below regarding the terms of an unopposed settlement submitted by the parties to the 2018 rate case that, if approved by the PUCT, establishes the amounts and timing of the return of protected and unprotected excess accumulated deferred income taxes to Entergy Texas customers. 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 are ongoing. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2018, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01547 per kWh to $0.01882 per kWh. The Arkansas Attorney General filed a response to Entergy Arkansas’s annual redetermination filing requesting that the APSC suspend the proposed tariff to investigate the amount of the redetermination or, alternatively, to allow recovery subject to refund. Among the reasons the Attorney General cited for suspension were questions pertaining to how Entergy Arkansas forecasted sales and potential implications of the Tax Act. Entergy Arkansas replied to the Attorney General’s filing and stated that, to the extent there are questions pertaining to its load forecasting or the operation of the energy cost recovery rider, those issues exceed the scope of the instant rate redetermination. Entergy Arkansas also stated that potential effects of the Tax Act are appropriately considered in the APSC’s separate proceeding looking at potential implications of the new tax law. The APSC general staff filed a reply to the Attorney General’s filing and agreed that Entergy Arkansas’s filing complied with the terms of the energy cost recovery rider. The redetermined rate became effective with the first billing cycle of April 2018. Subsequently in April 2018 the APSC issued an order declining to suspend Entergy Arkansas’s energy cost recovery rider rate and declining to require further investigation at that time of the issues suggested by the Attorney General in the proceeding. Following a period of discovery, the Attorney General filed a supplemental response in October 2018 raising new issues with Entergy Arkansas’s March 2018 rate redetermination and asserting that $45.7 million of the increase should be collected subject to refund pending further investigation. Also in October 2018, Entergy Arkansas filed to dismiss the Attorney General’s supplemental response, the APSC general staff filed a motion to strike the Attorney General’s filing, and the Attorney General filed its supplemental response disputing Entergy Arkansas and the APSC staff’s filing. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of the fuel adjustment clause filings by Entergy Gulf States Louisiana, whose business was combined with Entergy Louisiana in 2015. The audit includes a review of the reasonableness of charges flowed through Entergy Gulf States Louisiana’s fuel adjustment clause for the period from 2010 through 2013. Discovery commenced in July 2015. No report of audit has been issued. In May 2018 the LPSC staff provided notice of audits of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2016 through 2017. Discovery commenced in September 2018. No report of audit has been issued. 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 June 2017 the District Court issued a case management order setting a trial date in November 2018. Discovery ended in May 2018. In June 2018, Entergy filed motions for summary judgment, which are currently pending before the District Court. In July 2018 the Attorney General filed briefs opposing the summary judgment. In September 2018 the District Court held oral arguments on the Entergy companies’ motion to strike the Attorney General’s jury demand. At the hearing, the Attorney General withdrew his opposition to the Entergy companies’ motion to strike the Attorney General’s jury demand. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in an open PUCT proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. The pending appeals did not stay the PUCT’s decision, and Entergy Texas refunded to customers the $10.9 million over a four-month period beginning with the first billing cycle of July 2016. The federal appeal of the PUCT’s January 2016 decision was heard in December 2016, and the Federal District Court granted Entergy Texas’s requested relief. In January 2017 the PUCT and an intervenor filed petitions for appeal of the Federal District Court ruling to the U.S. Court of Appeals for the Fifth Circuit. Oral argument was held before the Fifth Circuit in February 2018. In April 2018 the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. In October 2018, Entergy Texas filed a notice of nonsuit in its appeal to the Travis County District Court regarding the PUCT’s January 2016 decision. In December 2017, Entergy Texas filed an application for a fuel refund of approximately $30.5 million for the months of May 2017 through October 2017. Also in December 2017, the PUCT’s ALJ approved the refund on an interim basis. For most customers, the refunds flowed through bills beginning January 2018 and continued through March 2018. The fuel refund was approved by the PUCT in March 2018. 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 information. Filings with the APSC (Entergy Arkansas) 2018 Formula Rate Plan Filing In July 2018, Entergy Arkansas filed with the APSC its 2018 formula rate plan filing to set its formula rate for the 2019 calendar year. The filing shows Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2019 test period to be below the formula rate plan bandwidth. Additionally, the filing includes the first netting adjustment under the current formula rate plan for the historical test year 2017, which is a comparison of projected costs and sales approved in the 2016 formula rate plan filing to actual 2017 costs and sales data. The filing includes a projected $73.4 million revenue deficiency for 2019 and a $95.6 million revenue deficiency for the 2017 historical test year, for a total revenue requirement of $169 million for this filing. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeds the constraint, the resulting increase is limited to four percent of total revenue, which is $65.4 million . The matter is scheduled for hearing in November 2018, and Entergy Arkansas requested that the APSC issue an order approving the proposed formula rate plan adjustment in December 2018, with the proposed formula rate plan adjustment effective with the first billing cycle of January 2019. In October 2018 the APSC staff and intervening parties filed their errors and objections to Entergy Arkansas’s 2018 formula rate plan filing, although no party proposed adjustments that would serve to reduce the requested revenue requirement below the annual revenue constraint. Entergy Arkansas also filed its rebuttal to the APSC staff and intervenors in October 2018. Later in October 2018 the parties submitted motions, which are pending with the APSC, to approve a partial settlement as to certain factual issues, to brief certain contested legal issues, and to cancel the hearing scheduled in November 2018. Similar to the 2018 filing, the formula rate plan filing that will be made in 2019 to set the formula rates for the 2020 calendar year will include a netting adjustment that will compare projected costs and sales for 2018 that were approved in the 2017 formula rate plan filing to actual 2018 costs and sales data. To the extent that Entergy Arkansas expects this netting adjustment to reflect actual 2018 revenues that are in excess of the actual costs for that year, Entergy Arkansas will record a regulatory provision in the fourth quarter 2018. Internal Restructuring As discussed in the Form 10-K, in November 2017, Entergy Arkansas filed an application with the APSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Arkansas to a new entity, which would ultimately be owned by an existing Entergy subsidiary holding company. Entergy Arkansas also filed a notice with the Missouri Public Service Commission in December 2017 out of an abundance of caution, although Entergy Arkansas does not serve any retail customers in Missouri. In April 2018 the Missouri Public Service Commission approved Entergy Arkansas’s filing. In July 2018, Entergy Arkansas filed a settlement, reached by all parties in the APSC proceeding, resolving all issues. The APSC approved the settlement agreement and restructuring in August 2018. Entergy expects to realize a permanent tax benefit at closing, and, pursuant to the settlement agreement, Entergy Arkansas will credit retail customers $39.6 million over six years, beginning in 2019. Entergy Arkansas has also received the required FERC and NRC approvals. The restructuring is anticipated to close on or before December 1, 2018. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2016 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2017, Entergy Louisiana filed its formula rate plan evaluation report for its 2016 calendar year operations. Rates reflecting the adjustments included in the formula rate plan evaluation report were implemented with the first billing cycle of September 2017, subject to refund. In September 2017 the LPSC issued its report indicating that no changes to Entergy Louisiana’s original formula rate plan evaluation report were required but reserved for several issues, including Entergy Louisiana’s September 2017 update to its formula rate plan evaluation report. In July 2018, Entergy Louisiana and the LPSC staff filed an unopposed joint report setting forth a correction to the annualization calculation, the effect of which was a net $3.5 million revenue requirement reduction, and indicating that there are no outstanding issues with the 2016 formula rate plan report, the supplemental report, or the interim updates. In September 2018 the LPSC approved the unopposed joint report. Formula Rate Plan Extension Request In August 2017, Entergy Louisiana filed a request with the LPSC seeking to extend its formula rate plan for three years (2017-2019) with limited modifications of its terms. Those modifications include: a one-time resetting of base rates to the midpoint of the band at Entergy Louisiana’s authorized return on equity of 9.95% for the 2017 test year; narrowing of the formula rate plan bandwidth from a total of 160 basis points to 80 basis points; and a forward-looking mechanism that would allow Entergy Louisiana to recover certain transmission-related costs contemporaneously with when those projects begin delivering benefits to customers. Several parties intervened in the proceeding and all parties participated in settlement discussions. In April 2018 the LPSC approved an unopposed joint motion filed by Entergy Louisiana and the LPSC staff that settles the matter. The settlement extends the formula rate plan for three years, providing for rates through at least August 2021. In addition to retaining the major features of the traditional formula rate plan, substantive features of the extended formula rate plan include: • a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation; • a 9.8% target earned return on common equity for the 2018 and 2019 test years; • narrowing of the common equity bandwidth to plus or minus 60 basis points around the target earned return on common equity; • a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity); • a framework for the flow back of certain tax benefits created by the Tax Act to customers, as described in “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above; and • a transmission recovery mechanism providing for the opportunity to recover certain transmission-related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism. 2017 Formula Rate Plan Filing In June 2018, Entergy Louisiana filed its formula rate plan evaluation report for its 2017 calendar year operations. As stated above under “Formula Rate Plan Extension Request,” for the 2017 test year there will be a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year. As such, base rider formula rate plan revenue is to be adjusted prospectively to increase or decrease the earned return on equity fully to the approved cost of equity of 9.95% . The 2017 test year evaluation report produced an earned return on equity of 8.16% , due in large part to revenue-neutral realignments to other recovery mechanisms. Without these realignments, the evaluation report produces an earned return on equity of 9.88% and a resulting base rider formula rate plan revenue increase of $4.8 million . Excluding the Tax Act credits provided for by the tax reform adjustment mechanisms, total formula rate plan revenues will further increase by a total of $98 million as a result of the evaluation report due to adjustments to the additional capacity and MISO cost recovery mechanisms of the formula rate plan, and implementation of the transmission recovery mechanism. In August 2018, Entergy Louisiana filed a supplemental formula rate plan evaluation report to reflect changes from the 2016 test year formula rate plan proceedings, a decrease to the transmission recovery mechanism to reflect lower actual capital additions, and a decrease to evaluation period expenses to reflect the terms of a new power sales agreement. Based on the August 2018 update, Entergy Louisiana would recognize a total decrease in formula rate plan revenue of approximately $17.6 million . Results of the updated 2017 evaluation report filing were implemented with the September 2018 billing month subject to refund and review by the LPSC staff and intervenors. In accordance with the terms of the formula rate plan, in September 2018 the LPSC staff and intervenors submitted their responses to Entergy Louisiana’s original formula rate plan evaluation report and supplemental compliance updates. The LPSC staff asserted objections/reservations regarding 1) Entergy Louisiana’s proposed rate adjustments associated with the return of excess accumulated deferred income taxes pursuant to the Tax Act and the treatment of accumulated deferred income taxes related to reductions of rate base; 2) Entergy Louisiana’s reservation regarding treatment of a regulatory asset related to certain special orders by the LPSC; and 3) test year expenses billed from Entergy Services to Entergy Louisiana. Intervenors also objected to Entergy Louisiana’s treatment of the regulatory asset related to certain special orders by the LPSC. A procedural schedule has not yet been established to resolve these 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. Union Power Station and Deactivation or Retirement Decisions for Entergy Louisiana Plants As discussed in the Form 10-K, as a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three-year term permitted by MISO. In March 2018 the LPSC adopted the ALJ’s recommended order finding that Entergy Louisiana did not demonstrate that its decision to permanently surrender transmission rights for the mothballed (not retired) Willow Glen 2 and 4 units was reasonable and that Entergy Louisiana should hold customers harmless from increased transmission expenses should those units be reactivated. Because no party or the LPSC suggested that Willow Glen 2 and 4 should be reactivated and because the cost to return those units to service far exceeds the revenue the units were expected to generate in MISO, Entergy Louisiana retired Willow Glen 2 and 4 in March 2018. Entergy Louisiana submitted a compliance filing regarding retirement of Willow Glen 2 and 4, and the LPSC closed the proceeding. Retail Rates - Gas 2017 Rate Stabilization Plan Filing In January 2018, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. The filing of the evaluation report for the test year 2017 reflected an earned return on common equity of 9.06% . This earned return is below the earnings sharing band of the rate stabilization plan and results in a rate increase of $0.1 million . Due to the enactment of the Tax Act in late-December 2017, Entergy Louisiana did not have adequate time to reflect the effects of this tax legislation in the rate stabilization plan. In April 2018 Entergy Louisiana filed a supplemental evaluation report for the test year ended September 2017, reflecting the effects of the Tax Act, including a proposal to use the unprotected excess accumulated deferred income taxes to offset storm restoration
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 See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements in the Form 10-K for discussion of the effects of the enactment in December 2017 of the Tax Cuts and Jobs Act (the Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. After assessing the activity described in more detail below regarding the status of the proposals the Registrant Subsidiaries made to their regulators for the return of unprotected excess accumulated deferred income taxes to customers, in 2018, Entergy and each of the Registrant Subsidiaries are reclassifying from the regulatory liability for income taxes to current liabilities the portion of their unprotected excess accumulated deferred income taxes that they expect to return to customers over the next twelve months. Entergy Arkansas See the Form 10-K for a discussion of the activity of the APSC and Entergy Arkansas after enactment of the Tax Act in December 2017. The APSC granted Entergy Arkansas’s request for clarification regarding the APSC’s order issued after enactment of the Tax Act. The APSC stated that its order was not a final determination and that the APSC had made no decision at that time on the appropriate final accounting or ratemaking treatment of the amounts in question. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its existing formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider includes a netting adjustment that compares actual annual costs and sales to the projected annual costs and sales used to establish rates. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed below, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true-up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits associated with the Tax Act. For the residential customer class, the unprotected excess accumulated deferred income taxes will be returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, the unprotected excess accumulated deferred income taxes will be returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included, with any over- or under-returned unprotected excess accumulated deferred income taxes to be credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. Entergy Louisiana See the Form 10-K for a discussion of the activity of the LPSC and Entergy Louisiana after enactment of the Tax Act in December 2017. In July 2018 the LPSC issued a proposed rule requiring utilities to adjust rates prospectively to reflect the lower tax rate (either through a formula rate plan or rate case), refund excess tax expense collected since January 1, 2018 until the lower tax rate is reflected in rates (with the refund occurring over one year), and refund excess accumulated deferred income taxes over two years. Entergy Louisiana believes that its formula rate plan settlement, approved in April 2018 and discussed below, addresses fully its obligations regarding the Tax Act and will seek such confirmation in its comments to the proposed rule. In the formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana will return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the parties agreed that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana would establish a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan are established (September 2018), and this regulatory liability will be returned to customers over the next formula rate plan rate-effective period (September 2018 through August 2019). As of September 30, 2018, Entergy Louisiana has a $67 million regulatory liability recorded pursuant to this provision of the settlement. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing, which, as discussed below, Entergy Louisiana filed in June 2018. Entergy Mississippi As discussed in the Form 10-K, after enactment of the Tax Act the MPSC ordered utilities, including Entergy Mississippi, that operate under a formula rate plan to file a description by February 26, 2018, of how the Tax Act will be reflected in the formula rate plan under which the utility operates. Entergy Mississippi's plan, as filed with the MPSC on February 26, 2018, included a request to reflect the changes related to the Tax Act in the 2018 formula rate plan filing. Entergy Mississippi filed its 2018 formula rate plan on March 15, 2018 and included a proposal to return all of its unprotected excess accumulated deferred income taxes to customers through rates or in exchange for other assets, or a combination of both, by the end of 2018. Also, in March 2018 the MPSC issued a subsequent order in its generic tax reform docket ordering utilities, including Entergy Mississippi, to explain the implementation of the utilities tax adjustment clause, or, in the alternative, why the tax adjustment clause is inapplicable; submit an analysis of the ratemaking effects of the Tax Act on current and future revenue requirements for rate schedules that include a gross-up for federal taxes; and make appropriate accounting entries to recognize the removal of excess deferred taxes from the balance of the utility’s accumulated deferred income tax account, or, in the alternative, explain why recording such entries is not appropriate. In April 2018, Entergy Mississippi filed its response to the MPSC stating that the tax adjustment clauses in its base rates are properly implemented through its formula rate plan. Entergy Mississippi also provided analysis of the ratemaking effects of the Tax Act. In June 2018, Entergy Mississippi and the Mississippi Public Utilities Staff entered into and filed a joint stipulation in Entergy Mississippi’s formula rate plan filing that addressed Entergy Mississippi’s 2018 formula rate plan evaluation report and the ratemaking effects of the Tax Act. Also in June 2018 the MPSC approved the stipulation, which provides for incorporating the reduction of the statutory federal income tax rate through the formula rate plan. Entergy Mississippi’s formula rate plan includes a look-back evaluation report filing in March 2019 that will compare actual 2018 results to the allowed return on rate base. The stipulation provides for the flow-back of protected excess accumulated deferred income taxes over approximately 40 years through the formula rate plan. The stipulation also provides for the offset of unprotected excess accumulated deferred income taxes of $127.2 million against net utility plant and $2.2 million against other regulatory assets, and the return to customers of the remaining balance of unprotected excess accumulated deferred income taxes as recovery of a portion of fuel oil inventory and customer bill credits over a three-month period from July 2018 through September 2018, with any true-up to be reflected in the November 2018 power management rider submittal. Entergy Mississippi recorded the reduction against net utility plant and other regulatory assets in June 2018. In third quarter 2018, Entergy Mississippi returned unprotected excess accumulated deferred income taxes of $25.8 million through customer bill credits and $5.8 million through the sale of fuel oil inventory. Entergy New Orleans As discussed in the Form 10-K, after enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy has submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what is presently reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits starting in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at FERC. The agreement in principle was approved by the City Council in June 2018. Entergy Texas As discussed below, in May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflect the inclusion of the federal income tax reductions due to the Tax Act. See the discussion below regarding the terms of an unopposed settlement submitted by the parties to the 2018 rate case that, if approved by the PUCT, establishes the amounts and timing of the return of protected and unprotected excess accumulated deferred income taxes to Entergy Texas customers. 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 are ongoing. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2018, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01547 per kWh to $0.01882 per kWh. The Arkansas Attorney General filed a response to Entergy Arkansas’s annual redetermination filing requesting that the APSC suspend the proposed tariff to investigate the amount of the redetermination or, alternatively, to allow recovery subject to refund. Among the reasons the Attorney General cited for suspension were questions pertaining to how Entergy Arkansas forecasted sales and potential implications of the Tax Act. Entergy Arkansas replied to the Attorney General’s filing and stated that, to the extent there are questions pertaining to its load forecasting or the operation of the energy cost recovery rider, those issues exceed the scope of the instant rate redetermination. Entergy Arkansas also stated that potential effects of the Tax Act are appropriately considered in the APSC’s separate proceeding looking at potential implications of the new tax law. The APSC general staff filed a reply to the Attorney General’s filing and agreed that Entergy Arkansas’s filing complied with the terms of the energy cost recovery rider. The redetermined rate became effective with the first billing cycle of April 2018. Subsequently in April 2018 the APSC issued an order declining to suspend Entergy Arkansas’s energy cost recovery rider rate and declining to require further investigation at that time of the issues suggested by the Attorney General in the proceeding. Following a period of discovery, the Attorney General filed a supplemental response in October 2018 raising new issues with Entergy Arkansas’s March 2018 rate redetermination and asserting that $45.7 million of the increase should be collected subject to refund pending further investigation. Also in October 2018, Entergy Arkansas filed to dismiss the Attorney General’s supplemental response, the APSC general staff filed a motion to strike the Attorney General’s filing, and the Attorney General filed its supplemental response disputing Entergy Arkansas and the APSC staff’s filing. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of the fuel adjustment clause filings by Entergy Gulf States Louisiana, whose business was combined with Entergy Louisiana in 2015. The audit includes a review of the reasonableness of charges flowed through Entergy Gulf States Louisiana’s fuel adjustment clause for the period from 2010 through 2013. Discovery commenced in July 2015. No report of audit has been issued. In May 2018 the LPSC staff provided notice of audits of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2016 through 2017. Discovery commenced in September 2018. No report of audit has been issued. 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 June 2017 the District Court issued a case management order setting a trial date in November 2018. Discovery ended in May 2018. In June 2018, Entergy filed motions for summary judgment, which are currently pending before the District Court. In July 2018 the Attorney General filed briefs opposing the summary judgment. In September 2018 the District Court held oral arguments on the Entergy companies’ motion to strike the Attorney General’s jury demand. At the hearing, the Attorney General withdrew his opposition to the Entergy companies’ motion to strike the Attorney General’s jury demand. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in an open PUCT proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. The pending appeals did not stay the PUCT’s decision, and Entergy Texas refunded to customers the $10.9 million over a four-month period beginning with the first billing cycle of July 2016. The federal appeal of the PUCT’s January 2016 decision was heard in December 2016, and the Federal District Court granted Entergy Texas’s requested relief. In January 2017 the PUCT and an intervenor filed petitions for appeal of the Federal District Court ruling to the U.S. Court of Appeals for the Fifth Circuit. Oral argument was held before the Fifth Circuit in February 2018. In April 2018 the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. In October 2018, Entergy Texas filed a notice of nonsuit in its appeal to the Travis County District Court regarding the PUCT’s January 2016 decision. In December 2017, Entergy Texas filed an application for a fuel refund of approximately $30.5 million for the months of May 2017 through October 2017. Also in December 2017, the PUCT’s ALJ approved the refund on an interim basis. For most customers, the refunds flowed through bills beginning January 2018 and continued through March 2018. The fuel refund was approved by the PUCT in March 2018. 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 information. Filings with the APSC (Entergy Arkansas) 2018 Formula Rate Plan Filing In July 2018, Entergy Arkansas filed with the APSC its 2018 formula rate plan filing to set its formula rate for the 2019 calendar year. The filing shows Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2019 test period to be below the formula rate plan bandwidth. Additionally, the filing includes the first netting adjustment under the current formula rate plan for the historical test year 2017, which is a comparison of projected costs and sales approved in the 2016 formula rate plan filing to actual 2017 costs and sales data. The filing includes a projected $73.4 million revenue deficiency for 2019 and a $95.6 million revenue deficiency for the 2017 historical test year, for a total revenue requirement of $169 million for this filing. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeds the constraint, the resulting increase is limited to four percent of total revenue, which is $65.4 million . The matter is scheduled for hearing in November 2018, and Entergy Arkansas requested that the APSC issue an order approving the proposed formula rate plan adjustment in December 2018, with the proposed formula rate plan adjustment effective with the first billing cycle of January 2019. In October 2018 the APSC staff and intervening parties filed their errors and objections to Entergy Arkansas’s 2018 formula rate plan filing, although no party proposed adjustments that would serve to reduce the requested revenue requirement below the annual revenue constraint. Entergy Arkansas also filed its rebuttal to the APSC staff and intervenors in October 2018. Later in October 2018 the parties submitted motions, which are pending with the APSC, to approve a partial settlement as to certain factual issues, to brief certain contested legal issues, and to cancel the hearing scheduled in November 2018. Similar to the 2018 filing, the formula rate plan filing that will be made in 2019 to set the formula rates for the 2020 calendar year will include a netting adjustment that will compare projected costs and sales for 2018 that were approved in the 2017 formula rate plan filing to actual 2018 costs and sales data. To the extent that Entergy Arkansas expects this netting adjustment to reflect actual 2018 revenues that are in excess of the actual costs for that year, Entergy Arkansas will record a regulatory provision in the fourth quarter 2018. Internal Restructuring As discussed in the Form 10-K, in November 2017, Entergy Arkansas filed an application with the APSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Arkansas to a new entity, which would ultimately be owned by an existing Entergy subsidiary holding company. Entergy Arkansas also filed a notice with the Missouri Public Service Commission in December 2017 out of an abundance of caution, although Entergy Arkansas does not serve any retail customers in Missouri. In April 2018 the Missouri Public Service Commission approved Entergy Arkansas’s filing. In July 2018, Entergy Arkansas filed a settlement, reached by all parties in the APSC proceeding, resolving all issues. The APSC approved the settlement agreement and restructuring in August 2018. Entergy expects to realize a permanent tax benefit at closing, and, pursuant to the settlement agreement, Entergy Arkansas will credit retail customers $39.6 million over six years, beginning in 2019. Entergy Arkansas has also received the required FERC and NRC approvals. The restructuring is anticipated to close on or before December 1, 2018. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2016 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2017, Entergy Louisiana filed its formula rate plan evaluation report for its 2016 calendar year operations. Rates reflecting the adjustments included in the formula rate plan evaluation report were implemented with the first billing cycle of September 2017, subject to refund. In September 2017 the LPSC issued its report indicating that no changes to Entergy Louisiana’s original formula rate plan evaluation report were required but reserved for several issues, including Entergy Louisiana’s September 2017 update to its formula rate plan evaluation report. In July 2018, Entergy Louisiana and the LPSC staff filed an unopposed joint report setting forth a correction to the annualization calculation, the effect of which was a net $3.5 million revenue requirement reduction, and indicating that there are no outstanding issues with the 2016 formula rate plan report, the supplemental report, or the interim updates. In September 2018 the LPSC approved the unopposed joint report. Formula Rate Plan Extension Request In August 2017, Entergy Louisiana filed a request with the LPSC seeking to extend its formula rate plan for three years (2017-2019) with limited modifications of its terms. Those modifications include: a one-time resetting of base rates to the midpoint of the band at Entergy Louisiana’s authorized return on equity of 9.95% for the 2017 test year; narrowing of the formula rate plan bandwidth from a total of 160 basis points to 80 basis points; and a forward-looking mechanism that would allow Entergy Louisiana to recover certain transmission-related costs contemporaneously with when those projects begin delivering benefits to customers. Several parties intervened in the proceeding and all parties participated in settlement discussions. In April 2018 the LPSC approved an unopposed joint motion filed by Entergy Louisiana and the LPSC staff that settles the matter. The settlement extends the formula rate plan for three years, providing for rates through at least August 2021. In addition to retaining the major features of the traditional formula rate plan, substantive features of the extended formula rate plan include: • a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation; • a 9.8% target earned return on common equity for the 2018 and 2019 test years; • narrowing of the common equity bandwidth to plus or minus 60 basis points around the target earned return on common equity; • a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity); • a framework for the flow back of certain tax benefits created by the Tax Act to customers, as described in “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above; and • a transmission recovery mechanism providing for the opportunity to recover certain transmission-related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism. 2017 Formula Rate Plan Filing In June 2018, Entergy Louisiana filed its formula rate plan evaluation report for its 2017 calendar year operations. As stated above under “Formula Rate Plan Extension Request,” for the 2017 test year there will be a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year. As such, base rider formula rate plan revenue is to be adjusted prospectively to increase or decrease the earned return on equity fully to the approved cost of equity of 9.95% . The 2017 test year evaluation report produced an earned return on equity of 8.16% , due in large part to revenue-neutral realignments to other recovery mechanisms. Without these realignments, the evaluation report produces an earned return on equity of 9.88% and a resulting base rider formula rate plan revenue increase of $4.8 million . Excluding the Tax Act credits provided for by the tax reform adjustment mechanisms, total formula rate plan revenues will further increase by a total of $98 million as a result of the evaluation report due to adjustments to the additional capacity and MISO cost recovery mechanisms of the formula rate plan, and implementation of the transmission recovery mechanism. In August 2018, Entergy Louisiana filed a supplemental formula rate plan evaluation report to reflect changes from the 2016 test year formula rate plan proceedings, a decrease to the transmission recovery mechanism to reflect lower actual capital additions, and a decrease to evaluation period expenses to reflect the terms of a new power sales agreement. Based on the August 2018 update, Entergy Louisiana would recognize a total decrease in formula rate plan revenue of approximately $17.6 million . Results of the updated 2017 evaluation report filing were implemented with the September 2018 billing month subject to refund and review by the LPSC staff and intervenors. In accordance with the terms of the formula rate plan, in September 2018 the LPSC staff and intervenors submitted their responses to Entergy Louisiana’s original formula rate plan evaluation report and supplemental compliance updates. The LPSC staff asserted objections/reservations regarding 1) Entergy Louisiana’s proposed rate adjustments associated with the return of excess accumulated deferred income taxes pursuant to the Tax Act and the treatment of accumulated deferred income taxes related to reductions of rate base; 2) Entergy Louisiana’s reservation regarding treatment of a regulatory asset related to certain special orders by the LPSC; and 3) test year expenses billed from Entergy Services to Entergy Louisiana. Intervenors also objected to Entergy Louisiana’s treatment of the regulatory asset related to certain special orders by the LPSC. A procedural schedule has not yet been established to resolve these 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. Union Power Station and Deactivation or Retirement Decisions for Entergy Louisiana Plants As discussed in the Form 10-K, as a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three-year term permitted by MISO. In March 2018 the LPSC adopted the ALJ’s recommended order finding that Entergy Louisiana did not demonstrate that its decision to permanently surrender transmission rights for the mothballed (not retired) Willow Glen 2 and 4 units was reasonable and that Entergy Louisiana should hold customers harmless from increased transmission expenses should those units be reactivated. Because no party or the LPSC suggested that Willow Glen 2 and 4 should be reactivated and because the cost to return those units to service far exceeds the revenue the units were expected to generate in MISO, Entergy Louisiana retired Willow Glen 2 and 4 in March 2018. Entergy Louisiana submitted a compliance filing regarding retirement of Willow Glen 2 and 4, and the LPSC closed the proceeding. Retail Rates - Gas 2017 Rate Stabilization Plan Filing In January 2018, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. The filing of the evaluation report for the test year 2017 reflected an earned return on common equity of 9.06% . This earned return is below the earnings sharing band of the rate stabilization plan and results in a rate increase of $0.1 million . Due to the enactment of the Tax Act in late-December 2017, Entergy Louisiana did not have adequate time to reflect the effects of this tax legislation in the rate stabilization plan. In April 2018 Entergy Louisiana filed a supplemental evaluation report for the test year ended September 2017, reflecting the effects of the Tax Act, including a proposal to use the unprotected excess accumulated deferred income taxes to offset storm restoration
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 See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements in the Form 10-K for discussion of the effects of the enactment in December 2017 of the Tax Cuts and Jobs Act (the Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. After assessing the activity described in more detail below regarding the status of the proposals the Registrant Subsidiaries made to their regulators for the return of unprotected excess accumulated deferred income taxes to customers, in 2018, Entergy and each of the Registrant Subsidiaries are reclassifying from the regulatory liability for income taxes to current liabilities the portion of their unprotected excess accumulated deferred income taxes that they expect to return to customers over the next twelve months. Entergy Arkansas See the Form 10-K for a discussion of the activity of the APSC and Entergy Arkansas after enactment of the Tax Act in December 2017. The APSC granted Entergy Arkansas’s request for clarification regarding the APSC’s order issued after enactment of the Tax Act. The APSC stated that its order was not a final determination and that the APSC had made no decision at that time on the appropriate final accounting or ratemaking treatment of the amounts in question. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its existing formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider includes a netting adjustment that compares actual annual costs and sales to the projected annual costs and sales used to establish rates. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed below, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true-up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits associated with the Tax Act. For the residential customer class, the unprotected excess accumulated deferred income taxes will be returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, the unprotected excess accumulated deferred income taxes will be returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included, with any over- or under-returned unprotected excess accumulated deferred income taxes to be credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. Entergy Louisiana See the Form 10-K for a discussion of the activity of the LPSC and Entergy Louisiana after enactment of the Tax Act in December 2017. In July 2018 the LPSC issued a proposed rule requiring utilities to adjust rates prospectively to reflect the lower tax rate (either through a formula rate plan or rate case), refund excess tax expense collected since January 1, 2018 until the lower tax rate is reflected in rates (with the refund occurring over one year), and refund excess accumulated deferred income taxes over two years. Entergy Louisiana believes that its formula rate plan settlement, approved in April 2018 and discussed below, addresses fully its obligations regarding the Tax Act and will seek such confirmation in its comments to the proposed rule. In the formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana will return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the parties agreed that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana would establish a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan are established (September 2018), and this regulatory liability will be returned to customers over the next formula rate plan rate-effective period (September 2018 through August 2019). As of September 30, 2018, Entergy Louisiana has a $67 million regulatory liability recorded pursuant to this provision of the settlement. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing, which, as discussed below, Entergy Louisiana filed in June 2018. Entergy Mississippi As discussed in the Form 10-K, after enactment of the Tax Act the MPSC ordered utilities, including Entergy Mississippi, that operate under a formula rate plan to file a description by February 26, 2018, of how the Tax Act will be reflected in the formula rate plan under which the utility operates. Entergy Mississippi's plan, as filed with the MPSC on February 26, 2018, included a request to reflect the changes related to the Tax Act in the 2018 formula rate plan filing. Entergy Mississippi filed its 2018 formula rate plan on March 15, 2018 and included a proposal to return all of its unprotected excess accumulated deferred income taxes to customers through rates or in exchange for other assets, or a combination of both, by the end of 2018. Also, in March 2018 the MPSC issued a subsequent order in its generic tax reform docket ordering utilities, including Entergy Mississippi, to explain the implementation of the utilities tax adjustment clause, or, in the alternative, why the tax adjustment clause is inapplicable; submit an analysis of the ratemaking effects of the Tax Act on current and future revenue requirements for rate schedules that include a gross-up for federal taxes; and make appropriate accounting entries to recognize the removal of excess deferred taxes from the balance of the utility’s accumulated deferred income tax account, or, in the alternative, explain why recording such entries is not appropriate. In April 2018, Entergy Mississippi filed its response to the MPSC stating that the tax adjustment clauses in its base rates are properly implemented through its formula rate plan. Entergy Mississippi also provided analysis of the ratemaking effects of the Tax Act. In June 2018, Entergy Mississippi and the Mississippi Public Utilities Staff entered into and filed a joint stipulation in Entergy Mississippi’s formula rate plan filing that addressed Entergy Mississippi’s 2018 formula rate plan evaluation report and the ratemaking effects of the Tax Act. Also in June 2018 the MPSC approved the stipulation, which provides for incorporating the reduction of the statutory federal income tax rate through the formula rate plan. Entergy Mississippi’s formula rate plan includes a look-back evaluation report filing in March 2019 that will compare actual 2018 results to the allowed return on rate base. The stipulation provides for the flow-back of protected excess accumulated deferred income taxes over approximately 40 years through the formula rate plan. The stipulation also provides for the offset of unprotected excess accumulated deferred income taxes of $127.2 million against net utility plant and $2.2 million against other regulatory assets, and the return to customers of the remaining balance of unprotected excess accumulated deferred income taxes as recovery of a portion of fuel oil inventory and customer bill credits over a three-month period from July 2018 through September 2018, with any true-up to be reflected in the November 2018 power management rider submittal. Entergy Mississippi recorded the reduction against net utility plant and other regulatory assets in June 2018. In third quarter 2018, Entergy Mississippi returned unprotected excess accumulated deferred income taxes of $25.8 million through customer bill credits and $5.8 million through the sale of fuel oil inventory. Entergy New Orleans As discussed in the Form 10-K, after enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy has submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what is presently reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits starting in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at FERC. The agreement in principle was approved by the City Council in June 2018. Entergy Texas As discussed below, in May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflect the inclusion of the federal income tax reductions due to the Tax Act. See the discussion below regarding the terms of an unopposed settlement submitted by the parties to the 2018 rate case that, if approved by the PUCT, establishes the amounts and timing of the return of protected and unprotected excess accumulated deferred income taxes to Entergy Texas customers. 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 are ongoing. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2018, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01547 per kWh to $0.01882 per kWh. The Arkansas Attorney General filed a response to Entergy Arkansas’s annual redetermination filing requesting that the APSC suspend the proposed tariff to investigate the amount of the redetermination or, alternatively, to allow recovery subject to refund. Among the reasons the Attorney General cited for suspension were questions pertaining to how Entergy Arkansas forecasted sales and potential implications of the Tax Act. Entergy Arkansas replied to the Attorney General’s filing and stated that, to the extent there are questions pertaining to its load forecasting or the operation of the energy cost recovery rider, those issues exceed the scope of the instant rate redetermination. Entergy Arkansas also stated that potential effects of the Tax Act are appropriately considered in the APSC’s separate proceeding looking at potential implications of the new tax law. The APSC general staff filed a reply to the Attorney General’s filing and agreed that Entergy Arkansas’s filing complied with the terms of the energy cost recovery rider. The redetermined rate became effective with the first billing cycle of April 2018. Subsequently in April 2018 the APSC issued an order declining to suspend Entergy Arkansas’s energy cost recovery rider rate and declining to require further investigation at that time of the issues suggested by the Attorney General in the proceeding. Following a period of discovery, the Attorney General filed a supplemental response in October 2018 raising new issues with Entergy Arkansas’s March 2018 rate redetermination and asserting that $45.7 million of the increase should be collected subject to refund pending further investigation. Also in October 2018, Entergy Arkansas filed to dismiss the Attorney General’s supplemental response, the APSC general staff filed a motion to strike the Attorney General’s filing, and the Attorney General filed its supplemental response disputing Entergy Arkansas and the APSC staff’s filing. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of the fuel adjustment clause filings by Entergy Gulf States Louisiana, whose business was combined with Entergy Louisiana in 2015. The audit includes a review of the reasonableness of charges flowed through Entergy Gulf States Louisiana’s fuel adjustment clause for the period from 2010 through 2013. Discovery commenced in July 2015. No report of audit has been issued. In May 2018 the LPSC staff provided notice of audits of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2016 through 2017. Discovery commenced in September 2018. No report of audit has been issued. 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 June 2017 the District Court issued a case management order setting a trial date in November 2018. Discovery ended in May 2018. In June 2018, Entergy filed motions for summary judgment, which are currently pending before the District Court. In July 2018 the Attorney General filed briefs opposing the summary judgment. In September 2018 the District Court held oral arguments on the Entergy companies’ motion to strike the Attorney General’s jury demand. At the hearing, the Attorney General withdrew his opposition to the Entergy companies’ motion to strike the Attorney General’s jury demand. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in an open PUCT proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. The pending appeals did not stay the PUCT’s decision, and Entergy Texas refunded to customers the $10.9 million over a four-month period beginning with the first billing cycle of July 2016. The federal appeal of the PUCT’s January 2016 decision was heard in December 2016, and the Federal District Court granted Entergy Texas’s requested relief. In January 2017 the PUCT and an intervenor filed petitions for appeal of the Federal District Court ruling to the U.S. Court of Appeals for the Fifth Circuit. Oral argument was held before the Fifth Circuit in February 2018. In April 2018 the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. In October 2018, Entergy Texas filed a notice of nonsuit in its appeal to the Travis County District Court regarding the PUCT’s January 2016 decision. In December 2017, Entergy Texas filed an application for a fuel refund of approximately $30.5 million for the months of May 2017 through October 2017. Also in December 2017, the PUCT’s ALJ approved the refund on an interim basis. For most customers, the refunds flowed through bills beginning January 2018 and continued through March 2018. The fuel refund was approved by the PUCT in March 2018. 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 information. Filings with the APSC (Entergy Arkansas) 2018 Formula Rate Plan Filing In July 2018, Entergy Arkansas filed with the APSC its 2018 formula rate plan filing to set its formula rate for the 2019 calendar year. The filing shows Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2019 test period to be below the formula rate plan bandwidth. Additionally, the filing includes the first netting adjustment under the current formula rate plan for the historical test year 2017, which is a comparison of projected costs and sales approved in the 2016 formula rate plan filing to actual 2017 costs and sales data. The filing includes a projected $73.4 million revenue deficiency for 2019 and a $95.6 million revenue deficiency for the 2017 historical test year, for a total revenue requirement of $169 million for this filing. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeds the constraint, the resulting increase is limited to four percent of total revenue, which is $65.4 million . The matter is scheduled for hearing in November 2018, and Entergy Arkansas requested that the APSC issue an order approving the proposed formula rate plan adjustment in December 2018, with the proposed formula rate plan adjustment effective with the first billing cycle of January 2019. In October 2018 the APSC staff and intervening parties filed their errors and objections to Entergy Arkansas’s 2018 formula rate plan filing, although no party proposed adjustments that would serve to reduce the requested revenue requirement below the annual revenue constraint. Entergy Arkansas also filed its rebuttal to the APSC staff and intervenors in October 2018. Later in October 2018 the parties submitted motions, which are pending with the APSC, to approve a partial settlement as to certain factual issues, to brief certain contested legal issues, and to cancel the hearing scheduled in November 2018. Similar to the 2018 filing, the formula rate plan filing that will be made in 2019 to set the formula rates for the 2020 calendar year will include a netting adjustment that will compare projected costs and sales for 2018 that were approved in the 2017 formula rate plan filing to actual 2018 costs and sales data. To the extent that Entergy Arkansas expects this netting adjustment to reflect actual 2018 revenues that are in excess of the actual costs for that year, Entergy Arkansas will record a regulatory provision in the fourth quarter 2018. Internal Restructuring As discussed in the Form 10-K, in November 2017, Entergy Arkansas filed an application with the APSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Arkansas to a new entity, which would ultimately be owned by an existing Entergy subsidiary holding company. Entergy Arkansas also filed a notice with the Missouri Public Service Commission in December 2017 out of an abundance of caution, although Entergy Arkansas does not serve any retail customers in Missouri. In April 2018 the Missouri Public Service Commission approved Entergy Arkansas’s filing. In July 2018, Entergy Arkansas filed a settlement, reached by all parties in the APSC proceeding, resolving all issues. The APSC approved the settlement agreement and restructuring in August 2018. Entergy expects to realize a permanent tax benefit at closing, and, pursuant to the settlement agreement, Entergy Arkansas will credit retail customers $39.6 million over six years, beginning in 2019. Entergy Arkansas has also received the required FERC and NRC approvals. The restructuring is anticipated to close on or before December 1, 2018. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2016 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2017, Entergy Louisiana filed its formula rate plan evaluation report for its 2016 calendar year operations. Rates reflecting the adjustments included in the formula rate plan evaluation report were implemented with the first billing cycle of September 2017, subject to refund. In September 2017 the LPSC issued its report indicating that no changes to Entergy Louisiana’s original formula rate plan evaluation report were required but reserved for several issues, including Entergy Louisiana’s September 2017 update to its formula rate plan evaluation report. In July 2018, Entergy Louisiana and the LPSC staff filed an unopposed joint report setting forth a correction to the annualization calculation, the effect of which was a net $3.5 million revenue requirement reduction, and indicating that there are no outstanding issues with the 2016 formula rate plan report, the supplemental report, or the interim updates. In September 2018 the LPSC approved the unopposed joint report. Formula Rate Plan Extension Request In August 2017, Entergy Louisiana filed a request with the LPSC seeking to extend its formula rate plan for three years (2017-2019) with limited modifications of its terms. Those modifications include: a one-time resetting of base rates to the midpoint of the band at Entergy Louisiana’s authorized return on equity of 9.95% for the 2017 test year; narrowing of the formula rate plan bandwidth from a total of 160 basis points to 80 basis points; and a forward-looking mechanism that would allow Entergy Louisiana to recover certain transmission-related costs contemporaneously with when those projects begin delivering benefits to customers. Several parties intervened in the proceeding and all parties participated in settlement discussions. In April 2018 the LPSC approved an unopposed joint motion filed by Entergy Louisiana and the LPSC staff that settles the matter. The settlement extends the formula rate plan for three years, providing for rates through at least August 2021. In addition to retaining the major features of the traditional formula rate plan, substantive features of the extended formula rate plan include: • a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation; • a 9.8% target earned return on common equity for the 2018 and 2019 test years; • narrowing of the common equity bandwidth to plus or minus 60 basis points around the target earned return on common equity; • a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity); • a framework for the flow back of certain tax benefits created by the Tax Act to customers, as described in “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above; and • a transmission recovery mechanism providing for the opportunity to recover certain transmission-related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism. 2017 Formula Rate Plan Filing In June 2018, Entergy Louisiana filed its formula rate plan evaluation report for its 2017 calendar year operations. As stated above under “Formula Rate Plan Extension Request,” for the 2017 test year there will be a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year. As such, base rider formula rate plan revenue is to be adjusted prospectively to increase or decrease the earned return on equity fully to the approved cost of equity of 9.95% . The 2017 test year evaluation report produced an earned return on equity of 8.16% , due in large part to revenue-neutral realignments to other recovery mechanisms. Without these realignments, the evaluation report produces an earned return on equity of 9.88% and a resulting base rider formula rate plan revenue increase of $4.8 million . Excluding the Tax Act credits provided for by the tax reform adjustment mechanisms, total formula rate plan revenues will further increase by a total of $98 million as a result of the evaluation report due to adjustments to the additional capacity and MISO cost recovery mechanisms of the formula rate plan, and implementation of the transmission recovery mechanism. In August 2018, Entergy Louisiana filed a supplemental formula rate plan evaluation report to reflect changes from the 2016 test year formula rate plan proceedings, a decrease to the transmission recovery mechanism to reflect lower actual capital additions, and a decrease to evaluation period expenses to reflect the terms of a new power sales agreement. Based on the August 2018 update, Entergy Louisiana would recognize a total decrease in formula rate plan revenue of approximately $17.6 million . Results of the updated 2017 evaluation report filing were implemented with the September 2018 billing month subject to refund and review by the LPSC staff and intervenors. In accordance with the terms of the formula rate plan, in September 2018 the LPSC staff and intervenors submitted their responses to Entergy Louisiana’s original formula rate plan evaluation report and supplemental compliance updates. The LPSC staff asserted objections/reservations regarding 1) Entergy Louisiana’s proposed rate adjustments associated with the return of excess accumulated deferred income taxes pursuant to the Tax Act and the treatment of accumulated deferred income taxes related to reductions of rate base; 2) Entergy Louisiana’s reservation regarding treatment of a regulatory asset related to certain special orders by the LPSC; and 3) test year expenses billed from Entergy Services to Entergy Louisiana. Intervenors also objected to Entergy Louisiana’s treatment of the regulatory asset related to certain special orders by the LPSC. A procedural schedule has not yet been established to resolve these 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. Union Power Station and Deactivation or Retirement Decisions for Entergy Louisiana Plants As discussed in the Form 10-K, as a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three-year term permitted by MISO. In March 2018 the LPSC adopted the ALJ’s recommended order finding that Entergy Louisiana did not demonstrate that its decision to permanently surrender transmission rights for the mothballed (not retired) Willow Glen 2 and 4 units was reasonable and that Entergy Louisiana should hold customers harmless from increased transmission expenses should those units be reactivated. Because no party or the LPSC suggested that Willow Glen 2 and 4 should be reactivated and because the cost to return those units to service far exceeds the revenue the units were expected to generate in MISO, Entergy Louisiana retired Willow Glen 2 and 4 in March 2018. Entergy Louisiana submitted a compliance filing regarding retirement of Willow Glen 2 and 4, and the LPSC closed the proceeding. Retail Rates - Gas 2017 Rate Stabilization Plan Filing In January 2018, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. The filing of the evaluation report for the test year 2017 reflected an earned return on common equity of 9.06% . This earned return is below the earnings sharing band of the rate stabilization plan and results in a rate increase of $0.1 million . Due to the enactment of the Tax Act in late-December 2017, Entergy Louisiana did not have adequate time to reflect the effects of this tax legislation in the rate stabilization plan. In April 2018 Entergy Louisiana filed a supplemental evaluation report for the test year ended September 2017, reflecting the effects of the Tax Act, including a proposal to use the unprotected excess accumulated deferred income taxes to offset storm restoration
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 See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements in the Form 10-K for discussion of the effects of the enactment in December 2017 of the Tax Cuts and Jobs Act (the Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. After assessing the activity described in more detail below regarding the status of the proposals the Registrant Subsidiaries made to their regulators for the return of unprotected excess accumulated deferred income taxes to customers, in 2018, Entergy and each of the Registrant Subsidiaries are reclassifying from the regulatory liability for income taxes to current liabilities the portion of their unprotected excess accumulated deferred income taxes that they expect to return to customers over the next twelve months. Entergy Arkansas See the Form 10-K for a discussion of the activity of the APSC and Entergy Arkansas after enactment of the Tax Act in December 2017. The APSC granted Entergy Arkansas’s request for clarification regarding the APSC’s order issued after enactment of the Tax Act. The APSC stated that its order was not a final determination and that the APSC had made no decision at that time on the appropriate final accounting or ratemaking treatment of the amounts in question. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its existing formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider includes a netting adjustment that compares actual annual costs and sales to the projected annual costs and sales used to establish rates. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed below, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true-up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits associated with the Tax Act. For the residential customer class, the unprotected excess accumulated deferred income taxes will be returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, the unprotected excess accumulated deferred income taxes will be returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included, with any over- or under-returned unprotected excess accumulated deferred income taxes to be credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. Entergy Louisiana See the Form 10-K for a discussion of the activity of the LPSC and Entergy Louisiana after enactment of the Tax Act in December 2017. In July 2018 the LPSC issued a proposed rule requiring utilities to adjust rates prospectively to reflect the lower tax rate (either through a formula rate plan or rate case), refund excess tax expense collected since January 1, 2018 until the lower tax rate is reflected in rates (with the refund occurring over one year), and refund excess accumulated deferred income taxes over two years. Entergy Louisiana believes that its formula rate plan settlement, approved in April 2018 and discussed below, addresses fully its obligations regarding the Tax Act and will seek such confirmation in its comments to the proposed rule. In the formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana will return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the parties agreed that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana would establish a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan are established (September 2018), and this regulatory liability will be returned to customers over the next formula rate plan rate-effective period (September 2018 through August 2019). As of September 30, 2018, Entergy Louisiana has a $67 million regulatory liability recorded pursuant to this provision of the settlement. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing, which, as discussed below, Entergy Louisiana filed in June 2018. Entergy Mississippi As discussed in the Form 10-K, after enactment of the Tax Act the MPSC ordered utilities, including Entergy Mississippi, that operate under a formula rate plan to file a description by February 26, 2018, of how the Tax Act will be reflected in the formula rate plan under which the utility operates. Entergy Mississippi's plan, as filed with the MPSC on February 26, 2018, included a request to reflect the changes related to the Tax Act in the 2018 formula rate plan filing. Entergy Mississippi filed its 2018 formula rate plan on March 15, 2018 and included a proposal to return all of its unprotected excess accumulated deferred income taxes to customers through rates or in exchange for other assets, or a combination of both, by the end of 2018. Also, in March 2018 the MPSC issued a subsequent order in its generic tax reform docket ordering utilities, including Entergy Mississippi, to explain the implementation of the utilities tax adjustment clause, or, in the alternative, why the tax adjustment clause is inapplicable; submit an analysis of the ratemaking effects of the Tax Act on current and future revenue requirements for rate schedules that include a gross-up for federal taxes; and make appropriate accounting entries to recognize the removal of excess deferred taxes from the balance of the utility’s accumulated deferred income tax account, or, in the alternative, explain why recording such entries is not appropriate. In April 2018, Entergy Mississippi filed its response to the MPSC stating that the tax adjustment clauses in its base rates are properly implemented through its formula rate plan. Entergy Mississippi also provided analysis of the ratemaking effects of the Tax Act. In June 2018, Entergy Mississippi and the Mississippi Public Utilities Staff entered into and filed a joint stipulation in Entergy Mississippi’s formula rate plan filing that addressed Entergy Mississippi’s 2018 formula rate plan evaluation report and the ratemaking effects of the Tax Act. Also in June 2018 the MPSC approved the stipulation, which provides for incorporating the reduction of the statutory federal income tax rate through the formula rate plan. Entergy Mississippi’s formula rate plan includes a look-back evaluation report filing in March 2019 that will compare actual 2018 results to the allowed return on rate base. The stipulation provides for the flow-back of protected excess accumulated deferred income taxes over approximately 40 years through the formula rate plan. The stipulation also provides for the offset of unprotected excess accumulated deferred income taxes of $127.2 million against net utility plant and $2.2 million against other regulatory assets, and the return to customers of the remaining balance of unprotected excess accumulated deferred income taxes as recovery of a portion of fuel oil inventory and customer bill credits over a three-month period from July 2018 through September 2018, with any true-up to be reflected in the November 2018 power management rider submittal. Entergy Mississippi recorded the reduction against net utility plant and other regulatory assets in June 2018. In third quarter 2018, Entergy Mississippi returned unprotected excess accumulated deferred income taxes of $25.8 million through customer bill credits and $5.8 million through the sale of fuel oil inventory. Entergy New Orleans As discussed in the Form 10-K, after enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy has submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what is presently reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits starting in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at FERC. The agreement in principle was approved by the City Council in June 2018. Entergy Texas As discussed below, in May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflect the inclusion of the federal income tax reductions due to the Tax Act. See the discussion below regarding the terms of an unopposed settlement submitted by the parties to the 2018 rate case that, if approved by the PUCT, establishes the amounts and timing of the return of protected and unprotected excess accumulated deferred income taxes to Entergy Texas customers. 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 are ongoing. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2018, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01547 per kWh to $0.01882 per kWh. The Arkansas Attorney General filed a response to Entergy Arkansas’s annual redetermination filing requesting that the APSC suspend the proposed tariff to investigate the amount of the redetermination or, alternatively, to allow recovery subject to refund. Among the reasons the Attorney General cited for suspension were questions pertaining to how Entergy Arkansas forecasted sales and potential implications of the Tax Act. Entergy Arkansas replied to the Attorney General’s filing and stated that, to the extent there are questions pertaining to its load forecasting or the operation of the energy cost recovery rider, those issues exceed the scope of the instant rate redetermination. Entergy Arkansas also stated that potential effects of the Tax Act are appropriately considered in the APSC’s separate proceeding looking at potential implications of the new tax law. The APSC general staff filed a reply to the Attorney General’s filing and agreed that Entergy Arkansas’s filing complied with the terms of the energy cost recovery rider. The redetermined rate became effective with the first billing cycle of April 2018. Subsequently in April 2018 the APSC issued an order declining to suspend Entergy Arkansas’s energy cost recovery rider rate and declining to require further investigation at that time of the issues suggested by the Attorney General in the proceeding. Following a period of discovery, the Attorney General filed a supplemental response in October 2018 raising new issues with Entergy Arkansas’s March 2018 rate redetermination and asserting that $45.7 million of the increase should be collected subject to refund pending further investigation. Also in October 2018, Entergy Arkansas filed to dismiss the Attorney General’s supplemental response, the APSC general staff filed a motion to strike the Attorney General’s filing, and the Attorney General filed its supplemental response disputing Entergy Arkansas and the APSC staff’s filing. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of the fuel adjustment clause filings by Entergy Gulf States Louisiana, whose business was combined with Entergy Louisiana in 2015. The audit includes a review of the reasonableness of charges flowed through Entergy Gulf States Louisiana’s fuel adjustment clause for the period from 2010 through 2013. Discovery commenced in July 2015. No report of audit has been issued. In May 2018 the LPSC staff provided notice of audits of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2016 through 2017. Discovery commenced in September 2018. No report of audit has been issued. 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 June 2017 the District Court issued a case management order setting a trial date in November 2018. Discovery ended in May 2018. In June 2018, Entergy filed motions for summary judgment, which are currently pending before the District Court. In July 2018 the Attorney General filed briefs opposing the summary judgment. In September 2018 the District Court held oral arguments on the Entergy companies’ motion to strike the Attorney General’s jury demand. At the hearing, the Attorney General withdrew his opposition to the Entergy companies’ motion to strike the Attorney General’s jury demand. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in an open PUCT proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. The pending appeals did not stay the PUCT’s decision, and Entergy Texas refunded to customers the $10.9 million over a four-month period beginning with the first billing cycle of July 2016. The federal appeal of the PUCT’s January 2016 decision was heard in December 2016, and the Federal District Court granted Entergy Texas’s requested relief. In January 2017 the PUCT and an intervenor filed petitions for appeal of the Federal District Court ruling to the U.S. Court of Appeals for the Fifth Circuit. Oral argument was held before the Fifth Circuit in February 2018. In April 2018 the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. In October 2018, Entergy Texas filed a notice of nonsuit in its appeal to the Travis County District Court regarding the PUCT’s January 2016 decision. In December 2017, Entergy Texas filed an application for a fuel refund of approximately $30.5 million for the months of May 2017 through October 2017. Also in December 2017, the PUCT’s ALJ approved the refund on an interim basis. For most customers, the refunds flowed through bills beginning January 2018 and continued through March 2018. The fuel refund was approved by the PUCT in March 2018. 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 information. Filings with the APSC (Entergy Arkansas) 2018 Formula Rate Plan Filing In July 2018, Entergy Arkansas filed with the APSC its 2018 formula rate plan filing to set its formula rate for the 2019 calendar year. The filing shows Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2019 test period to be below the formula rate plan bandwidth. Additionally, the filing includes the first netting adjustment under the current formula rate plan for the historical test year 2017, which is a comparison of projected costs and sales approved in the 2016 formula rate plan filing to actual 2017 costs and sales data. The filing includes a projected $73.4 million revenue deficiency for 2019 and a $95.6 million revenue deficiency for the 2017 historical test year, for a total revenue requirement of $169 million for this filing. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeds the constraint, the resulting increase is limited to four percent of total revenue, which is $65.4 million . The matter is scheduled for hearing in November 2018, and Entergy Arkansas requested that the APSC issue an order approving the proposed formula rate plan adjustment in December 2018, with the proposed formula rate plan adjustment effective with the first billing cycle of January 2019. In October 2018 the APSC staff and intervening parties filed their errors and objections to Entergy Arkansas’s 2018 formula rate plan filing, although no party proposed adjustments that would serve to reduce the requested revenue requirement below the annual revenue constraint. Entergy Arkansas also filed its rebuttal to the APSC staff and intervenors in October 2018. Later in October 2018 the parties submitted motions, which are pending with the APSC, to approve a partial settlement as to certain factual issues, to brief certain contested legal issues, and to cancel the hearing scheduled in November 2018. Similar to the 2018 filing, the formula rate plan filing that will be made in 2019 to set the formula rates for the 2020 calendar year will include a netting adjustment that will compare projected costs and sales for 2018 that were approved in the 2017 formula rate plan filing to actual 2018 costs and sales data. To the extent that Entergy Arkansas expects this netting adjustment to reflect actual 2018 revenues that are in excess of the actual costs for that year, Entergy Arkansas will record a regulatory provision in the fourth quarter 2018. Internal Restructuring As discussed in the Form 10-K, in November 2017, Entergy Arkansas filed an application with the APSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Arkansas to a new entity, which would ultimately be owned by an existing Entergy subsidiary holding company. Entergy Arkansas also filed a notice with the Missouri Public Service Commission in December 2017 out of an abundance of caution, although Entergy Arkansas does not serve any retail customers in Missouri. In April 2018 the Missouri Public Service Commission approved Entergy Arkansas’s filing. In July 2018, Entergy Arkansas filed a settlement, reached by all parties in the APSC proceeding, resolving all issues. The APSC approved the settlement agreement and restructuring in August 2018. Entergy expects to realize a permanent tax benefit at closing, and, pursuant to the settlement agreement, Entergy Arkansas will credit retail customers $39.6 million over six years, beginning in 2019. Entergy Arkansas has also received the required FERC and NRC approvals. The restructuring is anticipated to close on or before December 1, 2018. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2016 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2017, Entergy Louisiana filed its formula rate plan evaluation report for its 2016 calendar year operations. Rates reflecting the adjustments included in the formula rate plan evaluation report were implemented with the first billing cycle of September 2017, subject to refund. In September 2017 the LPSC issued its report indicating that no changes to Entergy Louisiana’s original formula rate plan evaluation report were required but reserved for several issues, including Entergy Louisiana’s September 2017 update to its formula rate plan evaluation report. In July 2018, Entergy Louisiana and the LPSC staff filed an unopposed joint report setting forth a correction to the annualization calculation, the effect of which was a net $3.5 million revenue requirement reduction, and indicating that there are no outstanding issues with the 2016 formula rate plan report, the supplemental report, or the interim updates. In September 2018 the LPSC approved the unopposed joint report. Formula Rate Plan Extension Request In August 2017, Entergy Louisiana filed a request with the LPSC seeking to extend its formula rate plan for three years (2017-2019) with limited modifications of its terms. Those modifications include: a one-time resetting of base rates to the midpoint of the band at Entergy Louisiana’s authorized return on equity of 9.95% for the 2017 test year; narrowing of the formula rate plan bandwidth from a total of 160 basis points to 80 basis points; and a forward-looking mechanism that would allow Entergy Louisiana to recover certain transmission-related costs contemporaneously with when those projects begin delivering benefits to customers. Several parties intervened in the proceeding and all parties participated in settlement discussions. In April 2018 the LPSC approved an unopposed joint motion filed by Entergy Louisiana and the LPSC staff that settles the matter. The settlement extends the formula rate plan for three years, providing for rates through at least August 2021. In addition to retaining the major features of the traditional formula rate plan, substantive features of the extended formula rate plan include: • a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation; • a 9.8% target earned return on common equity for the 2018 and 2019 test years; • narrowing of the common equity bandwidth to plus or minus 60 basis points around the target earned return on common equity; • a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity); • a framework for the flow back of certain tax benefits created by the Tax Act to customers, as described in “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above; and • a transmission recovery mechanism providing for the opportunity to recover certain transmission-related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism. 2017 Formula Rate Plan Filing In June 2018, Entergy Louisiana filed its formula rate plan evaluation report for its 2017 calendar year operations. As stated above under “Formula Rate Plan Extension Request,” for the 2017 test year there will be a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year. As such, base rider formula rate plan revenue is to be adjusted prospectively to increase or decrease the earned return on equity fully to the approved cost of equity of 9.95% . The 2017 test year evaluation report produced an earned return on equity of 8.16% , due in large part to revenue-neutral realignments to other recovery mechanisms. Without these realignments, the evaluation report produces an earned return on equity of 9.88% and a resulting base rider formula rate plan revenue increase of $4.8 million . Excluding the Tax Act credits provided for by the tax reform adjustment mechanisms, total formula rate plan revenues will further increase by a total of $98 million as a result of the evaluation report due to adjustments to the additional capacity and MISO cost recovery mechanisms of the formula rate plan, and implementation of the transmission recovery mechanism. In August 2018, Entergy Louisiana filed a supplemental formula rate plan evaluation report to reflect changes from the 2016 test year formula rate plan proceedings, a decrease to the transmission recovery mechanism to reflect lower actual capital additions, and a decrease to evaluation period expenses to reflect the terms of a new power sales agreement. Based on the August 2018 update, Entergy Louisiana would recognize a total decrease in formula rate plan revenue of approximately $17.6 million . Results of the updated 2017 evaluation report filing were implemented with the September 2018 billing month subject to refund and review by the LPSC staff and intervenors. In accordance with the terms of the formula rate plan, in September 2018 the LPSC staff and intervenors submitted their responses to Entergy Louisiana’s original formula rate plan evaluation report and supplemental compliance updates. The LPSC staff asserted objections/reservations regarding 1) Entergy Louisiana’s proposed rate adjustments associated with the return of excess accumulated deferred income taxes pursuant to the Tax Act and the treatment of accumulated deferred income taxes related to reductions of rate base; 2) Entergy Louisiana’s reservation regarding treatment of a regulatory asset related to certain special orders by the LPSC; and 3) test year expenses billed from Entergy Services to Entergy Louisiana. Intervenors also objected to Entergy Louisiana’s treatment of the regulatory asset related to certain special orders by the LPSC. A procedural schedule has not yet been established to resolve these 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. Union Power Station and Deactivation or Retirement Decisions for Entergy Louisiana Plants As discussed in the Form 10-K, as a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three-year term permitted by MISO. In March 2018 the LPSC adopted the ALJ’s recommended order finding that Entergy Louisiana did not demonstrate that its decision to permanently surrender transmission rights for the mothballed (not retired) Willow Glen 2 and 4 units was reasonable and that Entergy Louisiana should hold customers harmless from increased transmission expenses should those units be reactivated. Because no party or the LPSC suggested that Willow Glen 2 and 4 should be reactivated and because the cost to return those units to service far exceeds the revenue the units were expected to generate in MISO, Entergy Louisiana retired Willow Glen 2 and 4 in March 2018. Entergy Louisiana submitted a compliance filing regarding retirement of Willow Glen 2 and 4, and the LPSC closed the proceeding. Retail Rates - Gas 2017 Rate Stabilization Plan Filing In January 2018, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. The filing of the evaluation report for the test year 2017 reflected an earned return on common equity of 9.06% . This earned return is below the earnings sharing band of the rate stabilization plan and results in a rate increase of $0.1 million . Due to the enactment of the Tax Act in late-December 2017, Entergy Louisiana did not have adequate time to reflect the effects of this tax legislation in the rate stabilization plan. In April 2018 Entergy Louisiana filed a supplemental evaluation report for the test year ended September 2017, reflecting the effects of the Tax Act, including a proposal to use the unprotected excess accumulated deferred income taxes to offset storm restoration

Equity

Equity	9 Months Ended
	Sep. 30, 2018
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 September 30, 2018 2017 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $536.4 181.0 $2.96 $398.2 179.6 $2.22 Average dilutive effect of: Stock options 0.4 (0.01 ) 0.2 — Other equity plans 0.8 (0.01 ) 0.7 (0.01 ) Equity forwards 1.5 (0.02 ) — — Diluted earnings per share $536.4 183.7 $2.92 $398.2 180.5 $2.21 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.1 million for the three months ended September 30, 2018 and approximately 2.5 million for the three months ended September 30, 2017 . For the Nine Months Ended September 30, 2018 2017 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $914.6 180.8 $5.06 $890.7 179.5 $4.96 Average dilutive effect of: Stock options 0.3 (0.01 ) 0.2 (0.01 ) Other equity plans 0.7 (0.01 ) 0.5 (0.01 ) Equity forwards 0.9 (0.03 ) — — Diluted earnings per share $914.6 182.7 $5.01 $890.7 180.2 $4.94 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 nine months ended September 30, 2018 and approximately 3.3 million for the nine months ended September 30, 2017 . 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 $0.89 for the three months ended September 30, 2018 and $0.87 for the three months ended September 30, 2017. Dividends declared per common share were $2.67 for the nine months ended September 30, 2018 and $2.61 for the nine months ended September 30, 2017. Equity Forward Sale Agreements In June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. No amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forwards occur. The equity forwards require Entergy to, at its election prior to June 7, 2019, either (i) physically settle the transactions by issuing the total of 15.3 million shares of its common stock to the investment banks in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially $74.45 per share) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreements. If Entergy elects physical settlement of the forward sale agreements, it expects to use the net proceeds for general corporate purposes, which may include repayment of commercial paper, outstanding loans under Entergy's revolving credit facility, or other debt. Until settlement of the equity forwards, earnings per share dilution resulting from the agreements, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. If Entergy had elected to net share settle the forward sale agreements as of September 30, 2018, Entergy would have been required to deliver 1.4 million shares. Treasury Stock During the nine months ended September 30, 2018 , Entergy Corporation issued 613,662 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards. Entergy Corporation did not repurchase any of its common stock during the nine months ended September 30, 2018 . Retained Earnings On October 26, 2018, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.91 per share, payable on December 3, 2018, to holders of record as of November 8, 2018. Entergy implemented ASU No. 2016-01 “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” effective January 1, 2018. The ASU requires investments in equity securities, excluding those accounted for under the equity method or resulting in consolidation of the investee, to be measured at fair value with changes recognized in net income. Entergy implemented this standard using a modified retrospective method, and recorded an adjustment increasing retained earnings and reducing accumulated other comprehensive income by $633 million as of January 1, 2018 for the cumulative effect of the unrealized gains and losses on investments in equity securities held by the decommissioning trust funds that do not meet the criteria for regulatory accounting treatment. See Note 9 to the financial statements herein for further discussion of effects of the new standard. Entergy implemented ASU No. 2016-16, “Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory” effective January 1, 2018. The ASU requires entities to recognize the income tax consequences of intra-entity asset transfers, other than inventory, at the time the transfer occurs. Entergy implemented this standard using a modified retrospective method, and recorded an adjustment decreasing retained earnings by $56 million as of January 1, 2018 for the cumulative effect of recording deferred tax assets on previously-recognized intra-entity asset transfers. Entergy adopted ASU No. 2018-02, “Income Statement - Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income,” in the first quarter 2018. The ASU allows a one-time reclassification from accumulated other comprehensive income to retained earnings for certain tax effects resulting from the Tax Cuts and Jobs Act that would otherwise be stranded in accumulated other comprehensive income. Entergy’s policy for releasing income tax effects from accumulated other comprehensive income for available-for-sale securities is to use the portfolio approach. Entergy elected to reclassify the $15.5 million of stranded tax effects in accumulated other comprehensive income resulting from the Tax Cuts and Jobs Act to retained earnings ( $32 million decrease) or the regulatory liability for income taxes ( $16.5 million increase). Entergy’s reclassification only includes the effect of the change in the federal corporate income tax rate on accumulated other comprehensive income. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, July 1, 2018 ($14,874 ) ($589,926 ) ($8,842 ) ($613,642 ) Other comprehensive income (loss) before reclassifications (40,401 ) — (7,173 ) (47,574 ) Amounts reclassified from accumulated other comprehensive income (loss) 8,397 15,265 5,428 29,090 Net other comprehensive income (loss) for the period (32,004 ) 15,265 (1,745 ) (18,484 ) Ending balance, September 30, 2018 ($46,878 ) ($574,661 ) ($10,587 ) ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2017 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, July 1, 2017 $23,414 ($449,898 ) $479,257 $52,773 Other comprehensive income (loss) before reclassifications 27,884 — 35,630 63,514 Amounts reclassified from accumulated other comprehensive income (loss) (14,671 ) 12,297 (2,235 ) (4,609 ) Net other comprehensive income (loss) for the period 13,213 12,297 33,395 58,905 Ending balance, September 30, 2017 $36,627 ($437,601 ) $512,652 $111,678 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Ending balance, December 31, 2017 ($37,477 ) ($531,099 ) $545,045 ($23,531 ) Implementation of accounting standards — — (632,617 ) (632,617 ) Beginning balance, January 1, 2018 ($37,477 ) ($531,099 ) ($87,572 ) ($656,148 ) Other comprehensive income (loss) before reclassifications (31,816 ) — (50,958 ) (82,774 ) Amounts reclassified from accumulated other comprehensive income (loss) 30,171 47,404 13,716 91,291 Net other comprehensive income (loss) for the period (1,645 ) 47,404 (37,242 ) 8,517 Reclassification pursuant to ASU 2018-02 (7,756 ) (90,966 ) 114,227 15,505 Ending balance, September 30, 2018 ($46,878 ) ($574,661 ) ($10,587 ) ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2017 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, January 1, 2017 $3,993 ($469,446 ) $429,734 $748 ($34,971 ) Other comprehensive income (loss) before reclassifications 88,550 — 109,372 (748 ) 197,174 Amounts reclassified from accumulated other comprehensive income (loss) (55,916 ) 31,845 (26,454 ) — (50,525 ) Net other comprehensive income (loss) for the period 32,634 31,845 82,918 (748 ) 146,649 Ending balance, September 30, 2017 $36,627 ($437,601 ) $512,652 $— $111,678 The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2018 and 2017: Pension and Other 2018 2017 (In Thousands) Beginning balance, July 1, ($57,451 ) ($49,122 ) Amounts reclassified from accumulated other (500 ) (370 ) Net other comprehensive income (loss) for the period (500 ) (370 ) Ending balance, September 30, ($57,951 ) ($49,492 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2018 and 2017: Pension and Other 2018 2017 (In Thousands) Beginning balance, January 1, ($46,400 ) ($48,442 ) Amounts reclassified from accumulated other (1,502 ) (1,050 ) Net other comprehensive income (loss) for the period (1,502 ) (1,050 ) Reclassification pursuant to ASU 2018-02 (10,049 ) — Ending balance, September 30, ($57,951 ) ($49,492 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended September 30, 2018 and 2017 are as follows: Amounts reclassified Income Statement Location 2018 2017 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts ($10,566 ) $22,756 Competitive business operating revenues Interest rate swaps (63 ) (185 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges (10,629 ) 22,571 2,232 (7,900 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) ($8,397 ) $14,671 Pension and other postretirement liabilities Amortization of prior-service credit $5,425 $6,565 (a) Amortization of loss (24,740 ) (21,480 ) (a) Settlement loss (76 ) (4,200 ) (a) Total amortization (19,391 ) (19,115 ) 4,126 6,818 Income taxes Total amortization (net of tax) ($15,265 ) ($12,297 ) Net unrealized investment gain (loss) Realized gain (loss) ($8,589 ) $4,382 Interest and investment income 3,161 (2,147 ) Income taxes Total realized investment gain (loss) (net of tax) ($5,428 ) $2,235 Total reclassifications for the period (net of tax) ($29,090 ) $4,609 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the nine months ended September 30, 2018 and 2017 are as follows: Amounts reclassified from AOCI Income Statement Location 2018 2017 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts ($37,913 ) $86,678 Competitive business operating revenues Interest rate swaps (278 ) (654 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges (38,191 ) 86,024 8,020 (30,108 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) ($30,171 ) $55,916 Pension and other postretirement liabilities Amortization of prior-service credit $16,278 $19,691 (a) Amortization of loss (74,503 ) (64,605 ) (a) Settlement loss (2,098 ) (5,965 ) (a) Total amortization (60,323 ) (50,879 ) 12,919 19,034 Income taxes Total amortization (net of tax) ($47,404 ) ($31,845 ) Net unrealized investment gain (loss) Realized gain (loss) ($21,703 ) $51,871 Interest and investment income 7,987 (25,417 ) Income taxes Total realized investment gain (loss) (net of tax) ($13,716 ) $26,454 Total reclassifications for the period (net of tax) ($91,291 ) $50,525 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended September 30, 2018 and 2017 are as follows: Amounts reclassified Income Statement Location 2018 2017 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,934 $1,934 (a) Amortization of loss (1,257 ) (1,332 ) (a) Total amortization 677 602 (177 ) (232 ) Income taxes Total amortization (net of tax) 500 370 Total reclassifications for the period (net of tax) $500 $370 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the nine months ended September 30, 2018 and 2017 are as follows: Amounts reclassified Income Statement Location 2018 2017 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,802 $5,802 (a) Amortization of loss (3,770 ) (3,996 ) (a) Total amortization 2,032 1,806 (530 ) (756 ) Income taxes Total amortization (net of tax) 1,502 1,050 Total reclassifications for the period (net of tax) $1,502 $1,050 (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 September 30, 2018 2017 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $536.4 181.0 $2.96 $398.2 179.6 $2.22 Average dilutive effect of: Stock options 0.4 (0.01 ) 0.2 — Other equity plans 0.8 (0.01 ) 0.7 (0.01 ) Equity forwards 1.5 (0.02 ) — — Diluted earnings per share $536.4 183.7 $2.92 $398.2 180.5 $2.21 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.1 million for the three months ended September 30, 2018 and approximately 2.5 million for the three months ended September 30, 2017 . For the Nine Months Ended September 30, 2018 2017 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $914.6 180.8 $5.06 $890.7 179.5 $4.96 Average dilutive effect of: Stock options 0.3 (0.01 ) 0.2 (0.01 ) Other equity plans 0.7 (0.01 ) 0.5 (0.01 ) Equity forwards 0.9 (0.03 ) — — Diluted earnings per share $914.6 182.7 $5.01 $890.7 180.2 $4.94 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 nine months ended September 30, 2018 and approximately 3.3 million for the nine months ended September 30, 2017 . 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 $0.89 for the three months ended September 30, 2018 and $0.87 for the three months ended September 30, 2017. Dividends declared per common share were $2.67 for the nine months ended September 30, 2018 and $2.61 for the nine months ended September 30, 2017. Equity Forward Sale Agreements In June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. No amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forwards occur. The equity forwards require Entergy to, at its election prior to June 7, 2019, either (i) physically settle the transactions by issuing the total of 15.3 million shares of its common stock to the investment banks in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially $74.45 per share) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreements. If Entergy elects physical settlement of the forward sale agreements, it expects to use the net proceeds for general corporate purposes, which may include repayment of commercial paper, outstanding loans under Entergy's revolving credit facility, or other debt. Until settlement of the equity forwards, earnings per share dilution resulting from the agreements, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. If Entergy had elected to net share settle the forward sale agreements as of September 30, 2018, Entergy would have been required to deliver 1.4 million shares. Treasury Stock During the nine months ended September 30, 2018 , Entergy Corporation issued 613,662 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards. Entergy Corporation did not repurchase any of its common stock during the nine months ended September 30, 2018 . Retained Earnings On October 26, 2018, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.91 per share, payable on December 3, 2018, to holders of record as of November 8, 2018. Entergy implemented ASU No. 2016-01 “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” effective January 1, 2018. The ASU requires investments in equity securities, excluding those accounted for under the equity method or resulting in consolidation of the investee, to be measured at fair value with changes recognized in net income. Entergy implemented this standard using a modified retrospective method, and recorded an adjustment increasing retained earnings and reducing accumulated other comprehensive income by $633 million as of January 1, 2018 for the cumulative effect of the unrealized gains and losses on investments in equity securities held by the decommissioning trust funds that do not meet the criteria for regulatory accounting treatment. See Note 9 to the financial statements herein for further discussion of effects of the new standard. Entergy implemented ASU No. 2016-16, “Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory” effective January 1, 2018. The ASU requires entities to recognize the income tax consequences of intra-entity asset transfers, other than inventory, at the time the transfer occurs. Entergy implemented this standard using a modified retrospective method, and recorded an adjustment decreasing retained earnings by $56 million as of January 1, 2018 for the cumulative effect of recording deferred tax assets on previously-recognized intra-entity asset transfers. Entergy adopted ASU No. 2018-02, “Income Statement - Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income,” in the first quarter 2018. The ASU allows a one-time reclassification from accumulated other comprehensive income to retained earnings for certain tax effects resulting from the Tax Cuts and Jobs Act that would otherwise be stranded in accumulated other comprehensive income. Entergy’s policy for releasing income tax effects from accumulated other comprehensive income for available-for-sale securities is to use the portfolio approach. Entergy elected to reclassify the $15.5 million of stranded tax effects in accumulated other comprehensive income resulting from the Tax Cuts and Jobs Act to retained earnings ( $32 million decrease) or the regulatory liability for income taxes ( $16.5 million increase). Entergy’s reclassification only includes the effect of the change in the federal corporate income tax rate on accumulated other comprehensive income. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, July 1, 2018 ($14,874 ) ($589,926 ) ($8,842 ) ($613,642 ) Other comprehensive income (loss) before reclassifications (40,401 ) — (7,173 ) (47,574 ) Amounts reclassified from accumulated other comprehensive income (loss) 8,397 15,265 5,428 29,090 Net other comprehensive income (loss) for the period (32,004 ) 15,265 (1,745 ) (18,484 ) Ending balance, September 30, 2018 ($46,878 ) ($574,661 ) ($10,587 ) ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2017 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, July 1, 2017 $23,414 ($449,898 ) $479,257 $52,773 Other comprehensive income (loss) before reclassifications 27,884 — 35,630 63,514 Amounts reclassified from accumulated other comprehensive income (loss) (14,671 ) 12,297 (2,235 ) (4,609 ) Net other comprehensive income (loss) for the period 13,213 12,297 33,395 58,905 Ending balance, September 30, 2017 $36,627 ($437,601 ) $512,652 $111,678 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Ending balance, December 31, 2017 ($37,477 ) ($531,099 ) $545,045 ($23,531 ) Implementation of accounting standards — — (632,617 ) (632,617 ) Beginning balance, January 1, 2018 ($37,477 ) ($531,099 ) ($87,572 ) ($656,148 ) Other comprehensive income (loss) before reclassifications (31,816 ) — (50,958 ) (82,774 ) Amounts reclassified from accumulated other comprehensive income (loss) 30,171 47,404 13,716 91,291 Net other comprehensive income (loss) for the period (1,645 ) 47,404 (37,242 ) 8,517 Reclassification pursuant to ASU 2018-02 (7,756 ) (90,966 ) 114,227 15,505 Ending balance, September 30, 2018 ($46,878 ) ($574,661 ) ($10,587 ) ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2017 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, January 1, 2017 $3,993 ($469,446 ) $429,734 $748 ($34,971 ) Other comprehensive income (loss) before reclassifications 88,550 — 109,372 (748 ) 197,174 Amounts reclassified from accumulated other comprehensive income (loss) (55,916 ) 31,845 (26,454 ) — (50,525 ) Net other comprehensive income (loss) for the period 32,634 31,845 82,918 (748 ) 146,649 Ending balance, September 30, 2017 $36,627 ($437,601 ) $512,652 $— $111,678 The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2018 and 2017: Pension and Other 2018 2017 (In Thousands) Beginning balance, July 1, ($57,451 ) ($49,122 ) Amounts reclassified from accumulated other (500 ) (370 ) Net other comprehensive income (loss) for the period (500 ) (370 ) Ending balance, September 30, ($57,951 ) ($49,492 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2018 and 2017: Pension and Other 2018 2017 (In Thousands) Beginning balance, January 1, ($46,400 ) ($48,442 ) Amounts reclassified from accumulated other (1,502 ) (1,050 ) Net other comprehensive income (loss) for the period (1,502 ) (1,050 ) Reclassification pursuant to ASU 2018-02 (10,049 ) — Ending balance, September 30, ($57,951 ) ($49,492 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended September 30, 2018 and 2017 are as follows: Amounts reclassified Income Statement Location 2018 2017 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts ($10,566 ) $22,756 Competitive business operating revenues Interest rate swaps (63 ) (185 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges (10,629 ) 22,571 2,232 (7,900 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) ($8,397 ) $14,671 Pension and other postretirement liabilities Amortization of prior-service credit $5,425 $6,565 (a) Amortization of loss (24,740 ) (21,480 ) (a) Settlement loss (76 ) (4,200 ) (a) Total amortization (19,391 ) (19,115 ) 4,126 6,818 Income taxes Total amortization (net of tax) ($15,265 ) ($12,297 ) Net unrealized investment gain (loss) Realized gain (loss) ($8,589 ) $4,382 Interest and investment income 3,161 (2,147 ) Income taxes Total realized investment gain (loss) (net of tax) ($5,428 ) $2,235 Total reclassifications for the period (net of tax) ($29,090 ) $4,609 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the nine months ended September 30, 2018 and 2017 are as follows: Amounts reclassified from AOCI Income Statement Location 2018 2017 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts ($37,913 ) $86,678 Competitive business operating revenues Interest rate swaps (278 ) (654 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges (38,191 ) 86,024 8,020 (30,108 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) ($30,171 ) $55,916 Pension and other postretirement liabilities Amortization of prior-service credit $16,278 $19,691 (a) Amortization of loss (74,503 ) (64,605 ) (a) Settlement loss (2,098 ) (5,965 ) (a) Total amortization (60,323 ) (50,879 ) 12,919 19,034 Income taxes Total amortization (net of tax) ($47,404 ) ($31,845 ) Net unrealized investment gain (loss) Realized gain (loss) ($21,703 ) $51,871 Interest and investment income 7,987 (25,417 ) Income taxes Total realized investment gain (loss) (net of tax) ($13,716 ) $26,454 Total reclassifications for the period (net of tax) ($91,291 ) $50,525 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended September 30, 2018 and 2017 are as follows: Amounts reclassified Income Statement Location 2018 2017 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,934 $1,934 (a) Amortization of loss (1,257 ) (1,332 ) (a) Total amortization 677 602 (177 ) (232 ) Income taxes Total amortization (net of tax) 500 370 Total reclassifications for the period (net of tax) $500 $370 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the nine months ended September 30, 2018 and 2017 are as follows: Amounts reclassified Income Statement Location 2018 2017 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,802 $5,802 (a) Amortization of loss (3,770 ) (3,996 ) (a) Total amortization 2,032 1,806 (530 ) (756 ) Income taxes Total amortization (net of tax) 1,502 1,050 Total reclassifications for the period (net of tax) $1,502 $1,050 (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	9 Months Ended
	Sep. 30, 2018
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 nine months ended September 30, 2018 was 3.46% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $630 $6 $2,864 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At September 30, 2018 , Entergy Corporation had approximately $1,947 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2018 was 2.42% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2018 Letters of Credit Outstanding as of September 30, 2018 Entergy Arkansas April 2019 $20 million (b) 3.49% $— $— Entergy Arkansas September 2023 $150 million (c) 3.49% $— $— Entergy Louisiana September 2023 $350 million (c) 3.49% $— $— Entergy Mississippi May 2019 $37.5 million (d) 3.74% $— $— Entergy Mississippi May 2019 $35 million (d) 3.74% $— $— Entergy Mississippi May 2019 $10 million (d) 3.74% $— $— Entergy New Orleans November 2018 $25 million (c) 3.72% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.74% $— $1.3 million (a) For credit facilities with no borrowings as of September 30, 2018, the interest rate is the estimated interest rate as of September 30, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $22 million Entergy Mississippi $40 million 0.70% $11.2 million Entergy New Orleans $15 million 1.00% $2.1 million Entergy Texas $50 million 0.70% $20 million (a) As of September 30, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 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 are effective through October 31, 2019. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2018 (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 $34 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facility Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $145 million that expires in November 2020. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of September 30, 2018 , $132 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2018 was 3.37% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2018 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.18% $70.4 Entergy Louisiana River Bend VIE September 2021 $105 3.18% $34.5 Entergy Louisiana Waterford VIE September 2021 $105 3.18% $30.5 System Energy VIE September 2021 $120 3.18% $37.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2018 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 3.78% Series I due October 2018 $85 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 May 2018, Entergy Arkansas issued $250 million of 4.00% Series first mortgage bonds due June 2028. Entergy Arkansas expects to use the proceeds, together with other funds, to redeem $9.35 million of its 4.72% Series preferred stock, $7 million of its 4.32% Series preferred stock, and $15 million of its 4.56% Series preferred stock, and for general corporate purposes. (Entergy Louisiana) In March 2018, Entergy Louisiana issued $750 million of 4.00% collateral trust mortgage bonds due March 2033. Entergy Louisiana used a portion of the proceeds to repay at maturity its $375 million of 6.0% Series first mortgage bonds due May 2018; to repay borrowings from the money pool; and to repay borrowings under its $350 million credit facility. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power Station, and for general corporate purposes. In August 2018, Entergy Louisiana issued $600 million of 4.20% collateral trust mortgage bonds due September 2048. Entergy Louisiana used a portion of the proceeds to repay at maturity its $300 million of 6.5% Series first mortgage bonds due September 2018. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power Station, and for general corporate purposes. (Entergy New Orleans) In September 2018, Entergy New Orleans issued $60 million of 4.51% Series first mortgage bonds due September 2033. Entergy New Orleans is using the proceeds for general corporate purposes. (System Energy) In March 2018 the System Energy nuclear fuel trust variable interest entity issued $100 million of 3.42% Series J notes due April 2021. The System Energy nuclear fuel trust variable interest entity used the proceeds to purchase nuclear fuel. In October 2018 the System Energy nuclear fuel trust variable interest entity paid, at maturity, its $85 million of 3.78% Series I notes. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,515,836 $16,232,180 Entergy Arkansas $3,242,282 $3,031,681 Entergy Louisiana $6,761,123 $6,757,649 Entergy Mississippi $1,270,830 $1,234,124 Entergy New Orleans $491,570 $499,764 Entergy Texas $1,527,817 $1,546,101 System Energy $639,455 $610,485 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $186 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, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 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 nine months ended September 30, 2018 was 3.46% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $630 $6 $2,864 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At September 30, 2018 , Entergy Corporation had approximately $1,947 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2018 was 2.42% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2018 Letters of Credit Outstanding as of September 30, 2018 Entergy Arkansas April 2019 $20 million (b) 3.49% $— $— Entergy Arkansas September 2023 $150 million (c) 3.49% $— $— Entergy Louisiana September 2023 $350 million (c) 3.49% $— $— Entergy Mississippi May 2019 $37.5 million (d) 3.74% $— $— Entergy Mississippi May 2019 $35 million (d) 3.74% $— $— Entergy Mississippi May 2019 $10 million (d) 3.74% $— $— Entergy New Orleans November 2018 $25 million (c) 3.72% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.74% $— $1.3 million (a) For credit facilities with no borrowings as of September 30, 2018, the interest rate is the estimated interest rate as of September 30, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $22 million Entergy Mississippi $40 million 0.70% $11.2 million Entergy New Orleans $15 million 1.00% $2.1 million Entergy Texas $50 million 0.70% $20 million (a) As of September 30, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 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 are effective through October 31, 2019. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2018 (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 $34 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facility Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $145 million that expires in November 2020. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of September 30, 2018 , $132 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2018 was 3.37% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2018 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.18% $70.4 Entergy Louisiana River Bend VIE September 2021 $105 3.18% $34.5 Entergy Louisiana Waterford VIE September 2021 $105 3.18% $30.5 System Energy VIE September 2021 $120 3.18% $37.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2018 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 3.78% Series I due October 2018 $85 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 May 2018, Entergy Arkansas issued $250 million of 4.00% Series first mortgage bonds due June 2028. Entergy Arkansas expects to use the proceeds, together with other funds, to redeem $9.35 million of its 4.72% Series preferred stock, $7 million of its 4.32% Series preferred stock, and $15 million of its 4.56% Series preferred stock, and for general corporate purposes. (Entergy Louisiana) In March 2018, Entergy Louisiana issued $750 million of 4.00% collateral trust mortgage bonds due March 2033. Entergy Louisiana used a portion of the proceeds to repay at maturity its $375 million of 6.0% Series first mortgage bonds due May 2018; to repay borrowings from the money pool; and to repay borrowings under its $350 million credit facility. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power Station, and for general corporate purposes. In August 2018, Entergy Louisiana issued $600 million of 4.20% collateral trust mortgage bonds due September 2048. Entergy Louisiana used a portion of the proceeds to repay at maturity its $300 million of 6.5% Series first mortgage bonds due September 2018. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power Station, and for general corporate purposes. (Entergy New Orleans) In September 2018, Entergy New Orleans issued $60 million of 4.51% Series first mortgage bonds due September 2033. Entergy New Orleans is using the proceeds for general corporate purposes. (System Energy) In March 2018 the System Energy nuclear fuel trust variable interest entity issued $100 million of 3.42% Series J notes due April 2021. The System Energy nuclear fuel trust variable interest entity used the proceeds to purchase nuclear fuel. In October 2018 the System Energy nuclear fuel trust variable interest entity paid, at maturity, its $85 million of 3.78% Series I notes. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,515,836 $16,232,180 Entergy Arkansas $3,242,282 $3,031,681 Entergy Louisiana $6,761,123 $6,757,649 Entergy Mississippi $1,270,830 $1,234,124 Entergy New Orleans $491,570 $499,764 Entergy Texas $1,527,817 $1,546,101 System Energy $639,455 $610,485 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $186 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, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 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 nine months ended September 30, 2018 was 3.46% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $630 $6 $2,864 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At September 30, 2018 , Entergy Corporation had approximately $1,947 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2018 was 2.42% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2018 Letters of Credit Outstanding as of September 30, 2018 Entergy Arkansas April 2019 $20 million (b) 3.49% $— $— Entergy Arkansas September 2023 $150 million (c) 3.49% $— $— Entergy Louisiana September 2023 $350 million (c) 3.49% $— $— Entergy Mississippi May 2019 $37.5 million (d) 3.74% $— $— Entergy Mississippi May 2019 $35 million (d) 3.74% $— $— Entergy Mississippi May 2019 $10 million (d) 3.74% $— $— Entergy New Orleans November 2018 $25 million (c) 3.72% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.74% $— $1.3 million (a) For credit facilities with no borrowings as of September 30, 2018, the interest rate is the estimated interest rate as of September 30, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $22 million Entergy Mississippi $40 million 0.70% $11.2 million Entergy New Orleans $15 million 1.00% $2.1 million Entergy Texas $50 million 0.70% $20 million (a) As of September 30, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 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 are effective through October 31, 2019. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2018 (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 $34 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facility Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $145 million that expires in November 2020. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of September 30, 2018 , $132 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2018 was 3.37% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2018 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.18% $70.4 Entergy Louisiana River Bend VIE September 2021 $105 3.18% $34.5 Entergy Louisiana Waterford VIE September 2021 $105 3.18% $30.5 System Energy VIE September 2021 $120 3.18% $37.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2018 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 3.78% Series I due October 2018 $85 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 May 2018, Entergy Arkansas issued $250 million of 4.00% Series first mortgage bonds due June 2028. Entergy Arkansas expects to use the proceeds, together with other funds, to redeem $9.35 million of its 4.72% Series preferred stock, $7 million of its 4.32% Series preferred stock, and $15 million of its 4.56% Series preferred stock, and for general corporate purposes. (Entergy Louisiana) In March 2018, Entergy Louisiana issued $750 million of 4.00% collateral trust mortgage bonds due March 2033. Entergy Louisiana used a portion of the proceeds to repay at maturity its $375 million of 6.0% Series first mortgage bonds due May 2018; to repay borrowings from the money pool; and to repay borrowings under its $350 million credit facility. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power Station, and for general corporate purposes. In August 2018, Entergy Louisiana issued $600 million of 4.20% collateral trust mortgage bonds due September 2048. Entergy Louisiana used a portion of the proceeds to repay at maturity its $300 million of 6.5% Series first mortgage bonds due September 2018. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power Station, and for general corporate purposes. (Entergy New Orleans) In September 2018, Entergy New Orleans issued $60 million of 4.51% Series first mortgage bonds due September 2033. Entergy New Orleans is using the proceeds for general corporate purposes. (System Energy) In March 2018 the System Energy nuclear fuel trust variable interest entity issued $100 million of 3.42% Series J notes due April 2021. The System Energy nuclear fuel trust variable interest entity used the proceeds to purchase nuclear fuel. In October 2018 the System Energy nuclear fuel trust variable interest entity paid, at maturity, its $85 million of 3.78% Series I notes. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,515,836 $16,232,180 Entergy Arkansas $3,242,282 $3,031,681 Entergy Louisiana $6,761,123 $6,757,649 Entergy Mississippi $1,270,830 $1,234,124 Entergy New Orleans $491,570 $499,764 Entergy Texas $1,527,817 $1,546,101 System Energy $639,455 $610,485 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $186 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, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 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 nine months ended September 30, 2018 was 3.46% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $630 $6 $2,864 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At September 30, 2018 , Entergy Corporation had approximately $1,947 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2018 was 2.42% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2018 Letters of Credit Outstanding as of September 30, 2018 Entergy Arkansas April 2019 $20 million (b) 3.49% $— $— Entergy Arkansas September 2023 $150 million (c) 3.49% $— $— Entergy Louisiana September 2023 $350 million (c) 3.49% $— $— Entergy Mississippi May 2019 $37.5 million (d) 3.74% $— $— Entergy Mississippi May 2019 $35 million (d) 3.74% $— $— Entergy Mississippi May 2019 $10 million (d) 3.74% $— $— Entergy New Orleans November 2018 $25 million (c) 3.72% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.74% $— $1.3 million (a) For credit facilities with no borrowings as of September 30, 2018, the interest rate is the estimated interest rate as of September 30, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $22 million Entergy Mississippi $40 million 0.70% $11.2 million Entergy New Orleans $15 million 1.00% $2.1 million Entergy Texas $50 million 0.70% $20 million (a) As of September 30, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 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 are effective through October 31, 2019. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2018 (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 $34 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facility Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $145 million that expires in November 2020. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of September 30, 2018 , $132 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2018 was 3.37% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2018 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.18% $70.4 Entergy Louisiana River Bend VIE September 2021 $105 3.18% $34.5 Entergy Louisiana Waterford VIE September 2021 $105 3.18% $30.5 System Energy VIE September 2021 $120 3.18% $37.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2018 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 3.78% Series I due October 2018 $85 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 May 2018, Entergy Arkansas issued $250 million of 4.00% Series first mortgage bonds due June 2028. Entergy Arkansas expects to use the proceeds, together with other funds, to redeem $9.35 million of its 4.72% Series preferred stock, $7 million of its 4.32% Series preferred stock, and $15 million of its 4.56% Series preferred stock, and for general corporate purposes. (Entergy Louisiana) In March 2018, Entergy Louisiana issued $750 million of 4.00% collateral trust mortgage bonds due March 2033. Entergy Louisiana used a portion of the proceeds to repay at maturity its $375 million of 6.0% Series first mortgage bonds due May 2018; to repay borrowings from the money pool; and to repay borrowings under its $350 million credit facility. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power Station, and for general corporate purposes. In August 2018, Entergy Louisiana issued $600 million of 4.20% collateral trust mortgage bonds due September 2048. Entergy Louisiana used a portion of the proceeds to repay at maturity its $300 million of 6.5% Series first mortgage bonds due September 2018. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power Station, and for general corporate purposes. (Entergy New Orleans) In September 2018, Entergy New Orleans issued $60 million of 4.51% Series first mortgage bonds due September 2033. Entergy New Orleans is using the proceeds for general corporate purposes. (System Energy) In March 2018 the System Energy nuclear fuel trust variable interest entity issued $100 million of 3.42% Series J notes due April 2021. The System Energy nuclear fuel trust variable interest entity used the proceeds to purchase nuclear fuel. In October 2018 the System Energy nuclear fuel trust variable interest entity paid, at maturity, its $85 million of 3.78% Series I notes. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,515,836 $16,232,180 Entergy Arkansas $3,242,282 $3,031,681 Entergy Louisiana $6,761,123 $6,757,649 Entergy Mississippi $1,270,830 $1,234,124 Entergy New Orleans $491,570 $499,764 Entergy Texas $1,527,817 $1,546,101 System Energy $639,455 $610,485 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $186 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, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 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 nine months ended September 30, 2018 was 3.46% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $630 $6 $2,864 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At September 30, 2018 , Entergy Corporation had approximately $1,947 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2018 was 2.42% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2018 Letters of Credit Outstanding as of September 30, 2018 Entergy Arkansas April 2019 $20 million (b) 3.49% $— $— Entergy Arkansas September 2023 $150 million (c) 3.49% $— $— Entergy Louisiana September 2023 $350 million (c) 3.49% $— $— Entergy Mississippi May 2019 $37.5 million (d) 3.74% $— $— Entergy Mississippi May 2019 $35 million (d) 3.74% $— $— Entergy Mississippi May 2019 $10 million (d) 3.74% $— $— Entergy New Orleans November 2018 $25 million (c) 3.72% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.74% $— $1.3 million (a) For credit facilities with no borrowings as of September 30, 2018, the interest rate is the estimated interest rate as of September 30, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $22 million Entergy Mississippi $40 million 0.70% $11.2 million Entergy New Orleans $15 million 1.00% $2.1 million Entergy Texas $50 million 0.70% $20 million (a) As of September 30, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 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 are effective through October 31, 2019. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2018 (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 $34 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facility Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $145 million that expires in November 2020. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of September 30, 2018 , $132 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2018 was 3.37% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2018 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.18% $70.4 Entergy Louisiana River Bend VIE September 2021 $105 3.18% $34.5 Entergy Louisiana Waterford VIE September 2021 $105 3.18% $30.5 System Energy VIE September 2021 $120 3.18% $37.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2018 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 3.78% Series I due October 2018 $85 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 May 2018, Entergy Arkansas issued $250 million of 4.00% Series first mortgage bonds due June 2028. Entergy Arkansas expects to use the proceeds, together with other funds, to redeem $9.35 million of its 4.72% Series preferred stock, $7 million of its 4.32% Series preferred stock, and $15 million of its 4.56% Series preferred stock, and for general corporate purposes. (Entergy Louisiana) In March 2018, Entergy Louisiana issued $750 million of 4.00% collateral trust mortgage bonds due March 2033. Entergy Louisiana used a portion of the proceeds to repay at maturity its $375 million of 6.0% Series first mortgage bonds due May 2018; to repay borrowings from the money pool; and to repay borrowings under its $350 million credit facility. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power Station, and for general corporate purposes. In August 2018, Entergy Louisiana issued $600 million of 4.20% collateral trust mortgage bonds due September 2048. Entergy Louisiana used a portion of the proceeds to repay at maturity its $300 million of 6.5% Series first mortgage bonds due September 2018. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power Station, and for general corporate purposes. (Entergy New Orleans) In September 2018, Entergy New Orleans issued $60 million of 4.51% Series first mortgage bonds due September 2033. Entergy New Orleans is using the proceeds for general corporate purposes. (System Energy) In March 2018 the System Energy nuclear fuel trust variable interest entity issued $100 million of 3.42% Series J notes due April 2021. The System Energy nuclear fuel trust variable interest entity used the proceeds to purchase nuclear fuel. In October 2018 the System Energy nuclear fuel trust variable interest entity paid, at maturity, its $85 million of 3.78% Series I notes. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,515,836 $16,232,180 Entergy Arkansas $3,242,282 $3,031,681 Entergy Louisiana $6,761,123 $6,757,649 Entergy Mississippi $1,270,830 $1,234,124 Entergy New Orleans $491,570 $499,764 Entergy Texas $1,527,817 $1,546,101 System Energy $639,455 $610,485 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $186 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, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 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 nine months ended September 30, 2018 was 3.46% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $630 $6 $2,864 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At September 30, 2018 , Entergy Corporation had approximately $1,947 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2018 was 2.42% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2018 Letters of Credit Outstanding as of September 30, 2018 Entergy Arkansas April 2019 $20 million (b) 3.49% $— $— Entergy Arkansas September 2023 $150 million (c) 3.49% $— $— Entergy Louisiana September 2023 $350 million (c) 3.49% $— $— Entergy Mississippi May 2019 $37.5 million (d) 3.74% $— $— Entergy Mississippi May 2019 $35 million (d) 3.74% $— $— Entergy Mississippi May 2019 $10 million (d) 3.74% $— $— Entergy New Orleans November 2018 $25 million (c) 3.72% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.74% $— $1.3 million (a) For credit facilities with no borrowings as of September 30, 2018, the interest rate is the estimated interest rate as of September 30, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $22 million Entergy Mississippi $40 million 0.70% $11.2 million Entergy New Orleans $15 million 1.00% $2.1 million Entergy Texas $50 million 0.70% $20 million (a) As of September 30, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 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 are effective through October 31, 2019. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2018 (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 $34 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facility Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $145 million that expires in November 2020. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of September 30, 2018 , $132 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2018 was 3.37% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2018 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.18% $70.4 Entergy Louisiana River Bend VIE September 2021 $105 3.18% $34.5 Entergy Louisiana Waterford VIE September 2021 $105 3.18% $30.5 System Energy VIE September 2021 $120 3.18% $37.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2018 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 3.78% Series I due October 2018 $85 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 May 2018, Entergy Arkansas issued $250 million of 4.00% Series first mortgage bonds due June 2028. Entergy Arkansas expects to use the proceeds, together with other funds, to redeem $9.35 million of its 4.72% Series preferred stock, $7 million of its 4.32% Series preferred stock, and $15 million of its 4.56% Series preferred stock, and for general corporate purposes. (Entergy Louisiana) In March 2018, Entergy Louisiana issued $750 million of 4.00% collateral trust mortgage bonds due March 2033. Entergy Louisiana used a portion of the proceeds to repay at maturity its $375 million of 6.0% Series first mortgage bonds due May 2018; to repay borrowings from the money pool; and to repay borrowings under its $350 million credit facility. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power Station, and for general corporate purposes. In August 2018, Entergy Louisiana issued $600 million of 4.20% collateral trust mortgage bonds due September 2048. Entergy Louisiana used a portion of the proceeds to repay at maturity its $300 million of 6.5% Series first mortgage bonds due September 2018. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power Station, and for general corporate purposes. (Entergy New Orleans) In September 2018, Entergy New Orleans issued $60 million of 4.51% Series first mortgage bonds due September 2033. Entergy New Orleans is using the proceeds for general corporate purposes. (System Energy) In March 2018 the System Energy nuclear fuel trust variable interest entity issued $100 million of 3.42% Series J notes due April 2021. The System Energy nuclear fuel trust variable interest entity used the proceeds to purchase nuclear fuel. In October 2018 the System Energy nuclear fuel trust variable interest entity paid, at maturity, its $85 million of 3.78% Series I notes. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,515,836 $16,232,180 Entergy Arkansas $3,242,282 $3,031,681 Entergy Louisiana $6,761,123 $6,757,649 Entergy Mississippi $1,270,830 $1,234,124 Entergy New Orleans $491,570 $499,764 Entergy Texas $1,527,817 $1,546,101 System Energy $639,455 $610,485 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $186 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, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 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 nine months ended September 30, 2018 was 3.46% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $630 $6 $2,864 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At September 30, 2018 , Entergy Corporation had approximately $1,947 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2018 was 2.42% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2018 Letters of Credit Outstanding as of September 30, 2018 Entergy Arkansas April 2019 $20 million (b) 3.49% $— $— Entergy Arkansas September 2023 $150 million (c) 3.49% $— $— Entergy Louisiana September 2023 $350 million (c) 3.49% $— $— Entergy Mississippi May 2019 $37.5 million (d) 3.74% $— $— Entergy Mississippi May 2019 $35 million (d) 3.74% $— $— Entergy Mississippi May 2019 $10 million (d) 3.74% $— $— Entergy New Orleans November 2018 $25 million (c) 3.72% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.74% $— $1.3 million (a) For credit facilities with no borrowings as of September 30, 2018, the interest rate is the estimated interest rate as of September 30, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $22 million Entergy Mississippi $40 million 0.70% $11.2 million Entergy New Orleans $15 million 1.00% $2.1 million Entergy Texas $50 million 0.70% $20 million (a) As of September 30, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 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 are effective through October 31, 2019. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2018 (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 $34 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facility Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $145 million that expires in November 2020. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of September 30, 2018 , $132 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2018 was 3.37% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2018 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.18% $70.4 Entergy Louisiana River Bend VIE September 2021 $105 3.18% $34.5 Entergy Louisiana Waterford VIE September 2021 $105 3.18% $30.5 System Energy VIE September 2021 $120 3.18% $37.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2018 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 3.78% Series I due October 2018 $85 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 May 2018, Entergy Arkansas issued $250 million of 4.00% Series first mortgage bonds due June 2028. Entergy Arkansas expects to use the proceeds, together with other funds, to redeem $9.35 million of its 4.72% Series preferred stock, $7 million of its 4.32% Series preferred stock, and $15 million of its 4.56% Series preferred stock, and for general corporate purposes. (Entergy Louisiana) In March 2018, Entergy Louisiana issued $750 million of 4.00% collateral trust mortgage bonds due March 2033. Entergy Louisiana used a portion of the proceeds to repay at maturity its $375 million of 6.0% Series first mortgage bonds due May 2018; to repay borrowings from the money pool; and to repay borrowings under its $350 million credit facility. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power Station, and for general corporate purposes. In August 2018, Entergy Louisiana issued $600 million of 4.20% collateral trust mortgage bonds due September 2048. Entergy Louisiana used a portion of the proceeds to repay at maturity its $300 million of 6.5% Series first mortgage bonds due September 2018. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power Station, and for general corporate purposes. (Entergy New Orleans) In September 2018, Entergy New Orleans issued $60 million of 4.51% Series first mortgage bonds due September 2033. Entergy New Orleans is using the proceeds for general corporate purposes. (System Energy) In March 2018 the System Energy nuclear fuel trust variable interest entity issued $100 million of 3.42% Series J notes due April 2021. The System Energy nuclear fuel trust variable interest entity used the proceeds to purchase nuclear fuel. In October 2018 the System Energy nuclear fuel trust variable interest entity paid, at maturity, its $85 million of 3.78% Series I notes. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,515,836 $16,232,180 Entergy Arkansas $3,242,282 $3,031,681 Entergy Louisiana $6,761,123 $6,757,649 Entergy Mississippi $1,270,830 $1,234,124 Entergy New Orleans $491,570 $499,764 Entergy Texas $1,527,817 $1,546,101 System Energy $639,455 $610,485 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $186 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, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Stock-Based Compensation

Stock-Based Compensation	9 Months Ended
	Sep. 30, 2018
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 687,400 shares of its common stock under the 2015 Equity Ownership Plan during the first quarter 2018 with a fair value of $6.99 per option. As of September 30, 2018 , there were options on 4,071,301 shares of common stock outstanding with a weighted-average exercise price of $74.53 . The intrinsic value, which has no effect on net income, of the outstanding stock options is calculated by the positive difference between the weighted average exercise price of the stock options granted and Entergy Corporation’s common stock price as of September 30, 2018 . The aggregate intrinsic value of the stock options outstanding as of September 30, 2018 was $26.9 million . The following table includes financial information for outstanding stock options for the three months ended September 30, 2018 and 2017 : 2018 2017 (In Millions) Compensation expense included in Entergy’s net income $1.1 $1.1 Tax benefit recognized in Entergy’s net income $0.2 $0.5 Compensation cost capitalized as part of fixed assets and inventory $0.1 $0.2 The following table includes financial information for outstanding stock options for the nine months ended September 30, 2018 and 2017 : 2018 2017 (In Millions) Compensation expense included in Entergy’s net income $3.3 $3.3 Tax benefit recognized in Entergy’s net income $0.8 $1.3 Compensation cost capitalized as part of fixed assets and inventory $0.5 $0.6 Other Equity Awards In January 2018 the Board approved and Entergy granted 333,850 restricted stock awards and 182,408 long-term incentive awards under the 2015 Equity Ownership Plan. The restricted stock awards were made effective as of January 25, 2018 and were valued at $78.08 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. In addition, long-term incentive awards were 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 2018-2020 performance period, a cumulative utility earnings metric was added to the Long-Term Performance Unit Program to supplement the relative total shareholder return measure that historically has been used in this program with each measure equally weighted. The performance units were granted effective as of January 25, 2018 and half were valued at $78.08 per share, the closing price of Entergy’s common stock on that date; and half were valued at $86.75 per share based on various factors, primarily market conditions. See Note 12 to the financial statements in the Form 10-K for a description of the Long-Term Performance Unit Program. 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 3 -year vesting period. Performance units have the same dividend rights as shares of Entergy common stock, are considered issued and outstanding shares of Entergy upon vesting, and are expensed ratably over the 3 -year vesting period. The following table includes financial information for other outstanding equity awards for the three months ended September 30, 2018 and 2017: 2018 2017 (In Millions) Compensation expense included in Entergy’s net income $8.5 $7.6 Tax benefit recognized in Entergy’s net income $2.2 $3.0 Compensation cost capitalized as part of fixed assets and inventory $2.5 $2.1 The following table includes financial information for other outstanding equity awards for the nine months ended September 30, 2018 and 2017 : 2018 2017 (In Millions) Compensation expense included in Entergy’s net income $26.0 $24.1 Tax benefit recognized in Entergy’s net income $6.6 $9.3 Compensation cost capitalized as part of fixed assets and inventory $7.3 $6.3

Retirement And Other Postretire

Retirement And Other Postretirement Benefits	9 Months Ended
	Sep. 30, 2018
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) Entergy implemented ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” effective January 1, 2018. The ASU requires entities to report the service cost component of defined benefit pension cost and postretirement benefit cost (net benefit cost) in the same line item as other compensation costs arising from services rendered during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. The amendment regarding the presentation of net benefit cost was required to be applied retrospectively for all periods presented. In addition, the ASU allows only the service cost component of net benefit cost to be eligible for capitalization on a prospective basis. In accordance with the regulatory treatment of net benefit cost of the Registrant Subsidiaries, a regulatory asset/liability will be recorded in other regulatory assets/liabilities for the non-service cost components of net benefit cost that would have been capitalized. The retroactive presentation changes resulted in decreases in other operation and maintenance expenses and decreases in other income for the three months ended September 30, 2017, with no change in net income, of $30 million for Entergy. The retroactive presentation changes resulted in decreases in other operation and maintenance expenses and decreases in other income for the nine months ended September 30, 2017, with no change in net income, of $76 million for Entergy. The retroactive presentation changes resulted in decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income for the three months ended September 30, 2017 and for the nine months ended September 30, 2017, with no change in net income, of the following for the Registrant Subsidiaries: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Three months ended September 30, 2017 $3,515 $8,585 $778 $356 $43 $1,521 Nine months ended September 30, 2017 $9,995 $20,942 $1,862 $794 ($194 ) $4,778 The retroactive effect of the change for the years ended December 31, 2017, 2016, and 2015 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $101 million , $71 million , and $148 million , respectively, for Entergy. The retroactive effect of the change for the years ended December 31, 2017, 2016, and 2015 would be decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income, with no change in net income, of the following for the Registrant Subsidiaries: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) For the Year Ended December 31, 2017 $13,668 $27,796 $2,742 $1,293 $179 $6,190 For the Year Ended $13,392 $26,118 $2,424 $1,014 ($1,054 ) $5,088 For the Year Ended $30,671 $50,686 $6,268 $3,975 $4,000 $10,213 Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $116,256 $100,230 Interest cost on projected benefit obligation 200,562 195,618 Expected return on assets (331,605 ) (306,168 ) Amortization of prior service cost 297 195 Amortization of loss 205,578 170,790 Net pension costs $191,088 $160,665 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 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 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projects benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,270 $20,775 $4,416 $1,875 $4,092 $4,608 Interest cost on projected benefit obligation 38,832 44,427 11,196 5,373 10,176 9,273 Expected return on assets (61,281 ) (69,051 ) (18,393 ) (8,400 ) (18,540 ) (13,989 ) Amortization of loss 34,920 37,062 9,159 4,974 6,930 8,892 Net pension cost $27,741 $33,213 $6,378 $3,822 $2,658 $8,784 Non-Qualified Net Pension Cost Entergy recognized $4.2 million and $15.8 million in pension cost for its non-qualified pension plans in the third quarters of 2018 and 2017 , respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2018 and 2017 were settlement charges of $212 thousand and $11.6 million , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $19.7 million and $28.9 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2018 and 2017, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2018 and 2017 were settlement charges of $7 million and $15.5 million , respectively, related to the payment of lump sum benefits out of this plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $114 $42 $73 $20 $122 2017 $111 $46 $62 $18 $124 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarters of 2018 and 2017, were settlement charges of $7 thousand and $10 thousand , 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 nine months ended September 30, 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $369 $138 $230 $62 $529 2017 $483 $141 $189 $55 $377 Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 and 2017, were settlement charges of $30 thousand and $173 thousand , respectively, related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $20,346 $20,187 Interest cost on accumulated postretirement benefit obligation (APBO) 38,043 41,880 Expected return on assets (31,119 ) (28,224 ) Amortization of prior service credit (27,753 ) (31,068 ) Amortization of loss 10,296 16,428 Net other postretirement benefit cost $9,813 $19,203 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,589 $4,779 $870 $426 $1,116 $960 Interest cost on APBO 6,765 9,075 2,070 1,407 3,372 1,677 Expected return on assets (11,877 ) — (3,600 ) (3,477 ) (6,540 ) (2,151 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 3,345 1,395 1,257 315 2,478 1,170 Net other postretirement benefit cost ($3,012 ) $9,447 ($771 ) ($1,887 ) ($1,311 ) $522 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($71 ) $5,425 Amortization of loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($88 ) $6,565 Amortization of loss (18,451 ) (2,202 ) (827 ) (21,480 ) Settlement loss — — (4,200 ) (4,200 ) ($18,516 ) $4,516 ($5,115 ) ($19,115 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($297 ) $16,786 ($211 ) $16,278 Amortization of loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($195 ) $20,152 ($266 ) $19,691 Amortization of loss (55,351 ) (6,606 ) (2,648 ) (64,605 ) Settlement loss — — (5,965 ) (5,965 ) ($55,546 ) $13,546 ($8,879 ) ($50,879 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,594 ) (1,395 ) (7 ) (3,996 ) ($2,594 ) $4,407 ($7 ) $1,806 Employer Contributions Based on current assumptions, Entergy expects to contribute $383.5 million to its qualified pension plans in 2018. As of September 30, 2018 , Entergy had contributed $315.6 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 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,919 $14,933 $7,250 $10,883 $13,786 Pension contributions made through September 2018 $51,982 $58,363 $12,203 $5,938 $9,323 $11,152 Remaining estimated pension contributions to be made in 2018 $12,080 $13,556 $2,730 $1,312 $1,560 $2,634
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) Entergy implemented ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” effective January 1, 2018. The ASU requires entities to report the service cost component of defined benefit pension cost and postretirement benefit cost (net benefit cost) in the same line item as other compensation costs arising from services rendered during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. The amendment regarding the presentation of net benefit cost was required to be applied retrospectively for all periods presented. In addition, the ASU allows only the service cost component of net benefit cost to be eligible for capitalization on a prospective basis. In accordance with the regulatory treatment of net benefit cost of the Registrant Subsidiaries, a regulatory asset/liability will be recorded in other regulatory assets/liabilities for the non-service cost components of net benefit cost that would have been capitalized. The retroactive presentation changes resulted in decreases in other operation and maintenance expenses and decreases in other income for the three months ended September 30, 2017, with no change in net income, of $30 million for Entergy. The retroactive presentation changes resulted in decreases in other operation and maintenance expenses and decreases in other income for the nine months ended September 30, 2017, with no change in net income, of $76 million for Entergy. The retroactive presentation changes resulted in decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income for the three months ended September 30, 2017 and for the nine months ended September 30, 2017, with no change in net income, of the following for the Registrant Subsidiaries: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Three months ended September 30, 2017 $3,515 $8,585 $778 $356 $43 $1,521 Nine months ended September 30, 2017 $9,995 $20,942 $1,862 $794 ($194 ) $4,778 The retroactive effect of the change for the years ended December 31, 2017, 2016, and 2015 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $101 million , $71 million , and $148 million , respectively, for Entergy. The retroactive effect of the change for the years ended December 31, 2017, 2016, and 2015 would be decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income, with no change in net income, of the following for the Registrant Subsidiaries: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) For the Year Ended December 31, 2017 $13,668 $27,796 $2,742 $1,293 $179 $6,190 For the Year Ended $13,392 $26,118 $2,424 $1,014 ($1,054 ) $5,088 For the Year Ended $30,671 $50,686 $6,268 $3,975 $4,000 $10,213 Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $116,256 $100,230 Interest cost on projected benefit obligation 200,562 195,618 Expected return on assets (331,605 ) (306,168 ) Amortization of prior service cost 297 195 Amortization of loss 205,578 170,790 Net pension costs $191,088 $160,665 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 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 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projects benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,270 $20,775 $4,416 $1,875 $4,092 $4,608 Interest cost on projected benefit obligation 38,832 44,427 11,196 5,373 10,176 9,273 Expected return on assets (61,281 ) (69,051 ) (18,393 ) (8,400 ) (18,540 ) (13,989 ) Amortization of loss 34,920 37,062 9,159 4,974 6,930 8,892 Net pension cost $27,741 $33,213 $6,378 $3,822 $2,658 $8,784 Non-Qualified Net Pension Cost Entergy recognized $4.2 million and $15.8 million in pension cost for its non-qualified pension plans in the third quarters of 2018 and 2017 , respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2018 and 2017 were settlement charges of $212 thousand and $11.6 million , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $19.7 million and $28.9 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2018 and 2017, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2018 and 2017 were settlement charges of $7 million and $15.5 million , respectively, related to the payment of lump sum benefits out of this plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $114 $42 $73 $20 $122 2017 $111 $46 $62 $18 $124 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarters of 2018 and 2017, were settlement charges of $7 thousand and $10 thousand , 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 nine months ended September 30, 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $369 $138 $230 $62 $529 2017 $483 $141 $189 $55 $377 Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 and 2017, were settlement charges of $30 thousand and $173 thousand , respectively, related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $20,346 $20,187 Interest cost on accumulated postretirement benefit obligation (APBO) 38,043 41,880 Expected return on assets (31,119 ) (28,224 ) Amortization of prior service credit (27,753 ) (31,068 ) Amortization of loss 10,296 16,428 Net other postretirement benefit cost $9,813 $19,203 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,589 $4,779 $870 $426 $1,116 $960 Interest cost on APBO 6,765 9,075 2,070 1,407 3,372 1,677 Expected return on assets (11,877 ) — (3,600 ) (3,477 ) (6,540 ) (2,151 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 3,345 1,395 1,257 315 2,478 1,170 Net other postretirement benefit cost ($3,012 ) $9,447 ($771 ) ($1,887 ) ($1,311 ) $522 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($71 ) $5,425 Amortization of loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($88 ) $6,565 Amortization of loss (18,451 ) (2,202 ) (827 ) (21,480 ) Settlement loss — — (4,200 ) (4,200 ) ($18,516 ) $4,516 ($5,115 ) ($19,115 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($297 ) $16,786 ($211 ) $16,278 Amortization of loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($195 ) $20,152 ($266 ) $19,691 Amortization of loss (55,351 ) (6,606 ) (2,648 ) (64,605 ) Settlement loss — — (5,965 ) (5,965 ) ($55,546 ) $13,546 ($8,879 ) ($50,879 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,594 ) (1,395 ) (7 ) (3,996 ) ($2,594 ) $4,407 ($7 ) $1,806 Employer Contributions Based on current assumptions, Entergy expects to contribute $383.5 million to its qualified pension plans in 2018. As of September 30, 2018 , Entergy had contributed $315.6 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 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,919 $14,933 $7,250 $10,883 $13,786 Pension contributions made through September 2018 $51,982 $58,363 $12,203 $5,938 $9,323 $11,152 Remaining estimated pension contributions to be made in 2018 $12,080 $13,556 $2,730 $1,312 $1,560 $2,634
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) Entergy implemented ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” effective January 1, 2018. The ASU requires entities to report the service cost component of defined benefit pension cost and postretirement benefit cost (net benefit cost) in the same line item as other compensation costs arising from services rendered during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. The amendment regarding the presentation of net benefit cost was required to be applied retrospectively for all periods presented. In addition, the ASU allows only the service cost component of net benefit cost to be eligible for capitalization on a prospective basis. In accordance with the regulatory treatment of net benefit cost of the Registrant Subsidiaries, a regulatory asset/liability will be recorded in other regulatory assets/liabilities for the non-service cost components of net benefit cost that would have been capitalized. The retroactive presentation changes resulted in decreases in other operation and maintenance expenses and decreases in other income for the three months ended September 30, 2017, with no change in net income, of $30 million for Entergy. The retroactive presentation changes resulted in decreases in other operation and maintenance expenses and decreases in other income for the nine months ended September 30, 2017, with no change in net income, of $76 million for Entergy. The retroactive presentation changes resulted in decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income for the three months ended September 30, 2017 and for the nine months ended September 30, 2017, with no change in net income, of the following for the Registrant Subsidiaries: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Three months ended September 30, 2017 $3,515 $8,585 $778 $356 $43 $1,521 Nine months ended September 30, 2017 $9,995 $20,942 $1,862 $794 ($194 ) $4,778 The retroactive effect of the change for the years ended December 31, 2017, 2016, and 2015 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $101 million , $71 million , and $148 million , respectively, for Entergy. The retroactive effect of the change for the years ended December 31, 2017, 2016, and 2015 would be decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income, with no change in net income, of the following for the Registrant Subsidiaries: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) For the Year Ended December 31, 2017 $13,668 $27,796 $2,742 $1,293 $179 $6,190 For the Year Ended $13,392 $26,118 $2,424 $1,014 ($1,054 ) $5,088 For the Year Ended $30,671 $50,686 $6,268 $3,975 $4,000 $10,213 Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $116,256 $100,230 Interest cost on projected benefit obligation 200,562 195,618 Expected return on assets (331,605 ) (306,168 ) Amortization of prior service cost 297 195 Amortization of loss 205,578 170,790 Net pension costs $191,088 $160,665 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 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 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projects benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,270 $20,775 $4,416 $1,875 $4,092 $4,608 Interest cost on projected benefit obligation 38,832 44,427 11,196 5,373 10,176 9,273 Expected return on assets (61,281 ) (69,051 ) (18,393 ) (8,400 ) (18,540 ) (13,989 ) Amortization of loss 34,920 37,062 9,159 4,974 6,930 8,892 Net pension cost $27,741 $33,213 $6,378 $3,822 $2,658 $8,784 Non-Qualified Net Pension Cost Entergy recognized $4.2 million and $15.8 million in pension cost for its non-qualified pension plans in the third quarters of 2018 and 2017 , respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2018 and 2017 were settlement charges of $212 thousand and $11.6 million , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $19.7 million and $28.9 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2018 and 2017, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2018 and 2017 were settlement charges of $7 million and $15.5 million , respectively, related to the payment of lump sum benefits out of this plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $114 $42 $73 $20 $122 2017 $111 $46 $62 $18 $124 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarters of 2018 and 2017, were settlement charges of $7 thousand and $10 thousand , 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 nine months ended September 30, 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $369 $138 $230 $62 $529 2017 $483 $141 $189 $55 $377 Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 and 2017, were settlement charges of $30 thousand and $173 thousand , respectively, related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $20,346 $20,187 Interest cost on accumulated postretirement benefit obligation (APBO) 38,043 41,880 Expected return on assets (31,119 ) (28,224 ) Amortization of prior service credit (27,753 ) (31,068 ) Amortization of loss 10,296 16,428 Net other postretirement benefit cost $9,813 $19,203 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,589 $4,779 $870 $426 $1,116 $960 Interest cost on APBO 6,765 9,075 2,070 1,407 3,372 1,677 Expected return on assets (11,877 ) — (3,600 ) (3,477 ) (6,540 ) (2,151 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 3,345 1,395 1,257 315 2,478 1,170 Net other postretirement benefit cost ($3,012 ) $9,447 ($771 ) ($1,887 ) ($1,311 ) $522 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($71 ) $5,425 Amortization of loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($88 ) $6,565 Amortization of loss (18,451 ) (2,202 ) (827 ) (21,480 ) Settlement loss — — (4,200 ) (4,200 ) ($18,516 ) $4,516 ($5,115 ) ($19,115 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($297 ) $16,786 ($211 ) $16,278 Amortization of loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($195 ) $20,152 ($266 ) $19,691 Amortization of loss (55,351 ) (6,606 ) (2,648 ) (64,605 ) Settlement loss — — (5,965 ) (5,965 ) ($55,546 ) $13,546 ($8,879 ) ($50,879 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,594 ) (1,395 ) (7 ) (3,996 ) ($2,594 ) $4,407 ($7 ) $1,806 Employer Contributions Based on current assumptions, Entergy expects to contribute $383.5 million to its qualified pension plans in 2018. As of September 30, 2018 , Entergy had contributed $315.6 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 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,919 $14,933 $7,250 $10,883 $13,786 Pension contributions made through September 2018 $51,982 $58,363 $12,203 $5,938 $9,323 $11,152 Remaining estimated pension contributions to be made in 2018 $12,080 $13,556 $2,730 $1,312 $1,560 $2,634
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) Entergy implemented ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” effective January 1, 2018. The ASU requires entities to report the service cost component of defined benefit pension cost and postretirement benefit cost (net benefit cost) in the same line item as other compensation costs arising from services rendered during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. The amendment regarding the presentation of net benefit cost was required to be applied retrospectively for all periods presented. In addition, the ASU allows only the service cost component of net benefit cost to be eligible for capitalization on a prospective basis. In accordance with the regulatory treatment of net benefit cost of the Registrant Subsidiaries, a regulatory asset/liability will be recorded in other regulatory assets/liabilities for the non-service cost components of net benefit cost that would have been capitalized. The retroactive presentation changes resulted in decreases in other operation and maintenance expenses and decreases in other income for the three months ended September 30, 2017, with no change in net income, of $30 million for Entergy. The retroactive presentation changes resulted in decreases in other operation and maintenance expenses and decreases in other income for the nine months ended September 30, 2017, with no change in net income, of $76 million for Entergy. The retroactive presentation changes resulted in decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income for the three months ended September 30, 2017 and for the nine months ended September 30, 2017, with no change in net income, of the following for the Registrant Subsidiaries: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Three months ended September 30, 2017 $3,515 $8,585 $778 $356 $43 $1,521 Nine months ended September 30, 2017 $9,995 $20,942 $1,862 $794 ($194 ) $4,778 The retroactive effect of the change for the years ended December 31, 2017, 2016, and 2015 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $101 million , $71 million , and $148 million , respectively, for Entergy. The retroactive effect of the change for the years ended December 31, 2017, 2016, and 2015 would be decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income, with no change in net income, of the following for the Registrant Subsidiaries: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) For the Year Ended December 31, 2017 $13,668 $27,796 $2,742 $1,293 $179 $6,190 For the Year Ended $13,392 $26,118 $2,424 $1,014 ($1,054 ) $5,088 For the Year Ended $30,671 $50,686 $6,268 $3,975 $4,000 $10,213 Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $116,256 $100,230 Interest cost on projected benefit obligation 200,562 195,618 Expected return on assets (331,605 ) (306,168 ) Amortization of prior service cost 297 195 Amortization of loss 205,578 170,790 Net pension costs $191,088 $160,665 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 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 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projects benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,270 $20,775 $4,416 $1,875 $4,092 $4,608 Interest cost on projected benefit obligation 38,832 44,427 11,196 5,373 10,176 9,273 Expected return on assets (61,281 ) (69,051 ) (18,393 ) (8,400 ) (18,540 ) (13,989 ) Amortization of loss 34,920 37,062 9,159 4,974 6,930 8,892 Net pension cost $27,741 $33,213 $6,378 $3,822 $2,658 $8,784 Non-Qualified Net Pension Cost Entergy recognized $4.2 million and $15.8 million in pension cost for its non-qualified pension plans in the third quarters of 2018 and 2017 , respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2018 and 2017 were settlement charges of $212 thousand and $11.6 million , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $19.7 million and $28.9 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2018 and 2017, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2018 and 2017 were settlement charges of $7 million and $15.5 million , respectively, related to the payment of lump sum benefits out of this plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $114 $42 $73 $20 $122 2017 $111 $46 $62 $18 $124 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarters of 2018 and 2017, were settlement charges of $7 thousand and $10 thousand , 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 nine months ended September 30, 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $369 $138 $230 $62 $529 2017 $483 $141 $189 $55 $377 Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 and 2017, were settlement charges of $30 thousand and $173 thousand , respectively, related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $20,346 $20,187 Interest cost on accumulated postretirement benefit obligation (APBO) 38,043 41,880 Expected return on assets (31,119 ) (28,224 ) Amortization of prior service credit (27,753 ) (31,068 ) Amortization of loss 10,296 16,428 Net other postretirement benefit cost $9,813 $19,203 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,589 $4,779 $870 $426 $1,116 $960 Interest cost on APBO 6,765 9,075 2,070 1,407 3,372 1,677 Expected return on assets (11,877 ) — (3,600 ) (3,477 ) (6,540 ) (2,151 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 3,345 1,395 1,257 315 2,478 1,170 Net other postretirement benefit cost ($3,012 ) $9,447 ($771 ) ($1,887 ) ($1,311 ) $522 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($71 ) $5,425 Amortization of loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($88 ) $6,565 Amortization of loss (18,451 ) (2,202 ) (827 ) (21,480 ) Settlement loss — — (4,200 ) (4,200 ) ($18,516 ) $4,516 ($5,115 ) ($19,115 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($297 ) $16,786 ($211 ) $16,278 Amortization of loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($195 ) $20,152 ($266 ) $19,691 Amortization of loss (55,351 ) (6,606 ) (2,648 ) (64,605 ) Settlement loss — — (5,965 ) (5,965 ) ($55,546 ) $13,546 ($8,879 ) ($50,879 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,594 ) (1,395 ) (7 ) (3,996 ) ($2,594 ) $4,407 ($7 ) $1,806 Employer Contributions Based on current assumptions, Entergy expects to contribute $383.5 million to its qualified pension plans in 2018. As of September 30, 2018 , Entergy had contributed $315.6 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 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,919 $14,933 $7,250 $10,883 $13,786 Pension contributions made through September 2018 $51,982 $58,363 $12,203 $5,938 $9,323 $11,152 Remaining estimated pension contributions to be made in 2018 $12,080 $13,556 $2,730 $1,312 $1,560 $2,634
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) Entergy implemented ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” effective January 1, 2018. The ASU requires entities to report the service cost component of defined benefit pension cost and postretirement benefit cost (net benefit cost) in the same line item as other compensation costs arising from services rendered during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. The amendment regarding the presentation of net benefit cost was required to be applied retrospectively for all periods presented. In addition, the ASU allows only the service cost component of net benefit cost to be eligible for capitalization on a prospective basis. In accordance with the regulatory treatment of net benefit cost of the Registrant Subsidiaries, a regulatory asset/liability will be recorded in other regulatory assets/liabilities for the non-service cost components of net benefit cost that would have been capitalized. The retroactive presentation changes resulted in decreases in other operation and maintenance expenses and decreases in other income for the three months ended September 30, 2017, with no change in net income, of $30 million for Entergy. The retroactive presentation changes resulted in decreases in other operation and maintenance expenses and decreases in other income for the nine months ended September 30, 2017, with no change in net income, of $76 million for Entergy. The retroactive presentation changes resulted in decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income for the three months ended September 30, 2017 and for the nine months ended September 30, 2017, with no change in net income, of the following for the Registrant Subsidiaries: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Three months ended September 30, 2017 $3,515 $8,585 $778 $356 $43 $1,521 Nine months ended September 30, 2017 $9,995 $20,942 $1,862 $794 ($194 ) $4,778 The retroactive effect of the change for the years ended December 31, 2017, 2016, and 2015 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $101 million , $71 million , and $148 million , respectively, for Entergy. The retroactive effect of the change for the years ended December 31, 2017, 2016, and 2015 would be decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income, with no change in net income, of the following for the Registrant Subsidiaries: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) For the Year Ended December 31, 2017 $13,668 $27,796 $2,742 $1,293 $179 $6,190 For the Year Ended $13,392 $26,118 $2,424 $1,014 ($1,054 ) $5,088 For the Year Ended $30,671 $50,686 $6,268 $3,975 $4,000 $10,213 Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $116,256 $100,230 Interest cost on projected benefit obligation 200,562 195,618 Expected return on assets (331,605 ) (306,168 ) Amortization of prior service cost 297 195 Amortization of loss 205,578 170,790 Net pension costs $191,088 $160,665 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 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 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projects benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,270 $20,775 $4,416 $1,875 $4,092 $4,608 Interest cost on projected benefit obligation 38,832 44,427 11,196 5,373 10,176 9,273 Expected return on assets (61,281 ) (69,051 ) (18,393 ) (8,400 ) (18,540 ) (13,989 ) Amortization of loss 34,920 37,062 9,159 4,974 6,930 8,892 Net pension cost $27,741 $33,213 $6,378 $3,822 $2,658 $8,784 Non-Qualified Net Pension Cost Entergy recognized $4.2 million and $15.8 million in pension cost for its non-qualified pension plans in the third quarters of 2018 and 2017 , respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2018 and 2017 were settlement charges of $212 thousand and $11.6 million , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $19.7 million and $28.9 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2018 and 2017, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2018 and 2017 were settlement charges of $7 million and $15.5 million , respectively, related to the payment of lump sum benefits out of this plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $114 $42 $73 $20 $122 2017 $111 $46 $62 $18 $124 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarters of 2018 and 2017, were settlement charges of $7 thousand and $10 thousand , 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 nine months ended September 30, 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $369 $138 $230 $62 $529 2017 $483 $141 $189 $55 $377 Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 and 2017, were settlement charges of $30 thousand and $173 thousand , respectively, related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $20,346 $20,187 Interest cost on accumulated postretirement benefit obligation (APBO) 38,043 41,880 Expected return on assets (31,119 ) (28,224 ) Amortization of prior service credit (27,753 ) (31,068 ) Amortization of loss 10,296 16,428 Net other postretirement benefit cost $9,813 $19,203 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,589 $4,779 $870 $426 $1,116 $960 Interest cost on APBO 6,765 9,075 2,070 1,407 3,372 1,677 Expected return on assets (11,877 ) — (3,600 ) (3,477 ) (6,540 ) (2,151 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 3,345 1,395 1,257 315 2,478 1,170 Net other postretirement benefit cost ($3,012 ) $9,447 ($771 ) ($1,887 ) ($1,311 ) $522 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($71 ) $5,425 Amortization of loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($88 ) $6,565 Amortization of loss (18,451 ) (2,202 ) (827 ) (21,480 ) Settlement loss — — (4,200 ) (4,200 ) ($18,516 ) $4,516 ($5,115 ) ($19,115 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($297 ) $16,786 ($211 ) $16,278 Amortization of loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($195 ) $20,152 ($266 ) $19,691 Amortization of loss (55,351 ) (6,606 ) (2,648 ) (64,605 ) Settlement loss — — (5,965 ) (5,965 ) ($55,546 ) $13,546 ($8,879 ) ($50,879 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,594 ) (1,395 ) (7 ) (3,996 ) ($2,594 ) $4,407 ($7 ) $1,806 Employer Contributions Based on current assumptions, Entergy expects to contribute $383.5 million to its qualified pension plans in 2018. As of September 30, 2018 , Entergy had contributed $315.6 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 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,919 $14,933 $7,250 $10,883 $13,786 Pension contributions made through September 2018 $51,982 $58,363 $12,203 $5,938 $9,323 $11,152 Remaining estimated pension contributions to be made in 2018 $12,080 $13,556 $2,730 $1,312 $1,560 $2,634
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) Entergy implemented ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” effective January 1, 2018. The ASU requires entities to report the service cost component of defined benefit pension cost and postretirement benefit cost (net benefit cost) in the same line item as other compensation costs arising from services rendered during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. The amendment regarding the presentation of net benefit cost was required to be applied retrospectively for all periods presented. In addition, the ASU allows only the service cost component of net benefit cost to be eligible for capitalization on a prospective basis. In accordance with the regulatory treatment of net benefit cost of the Registrant Subsidiaries, a regulatory asset/liability will be recorded in other regulatory assets/liabilities for the non-service cost components of net benefit cost that would have been capitalized. The retroactive presentation changes resulted in decreases in other operation and maintenance expenses and decreases in other income for the three months ended September 30, 2017, with no change in net income, of $30 million for Entergy. The retroactive presentation changes resulted in decreases in other operation and maintenance expenses and decreases in other income for the nine months ended September 30, 2017, with no change in net income, of $76 million for Entergy. The retroactive presentation changes resulted in decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income for the three months ended September 30, 2017 and for the nine months ended September 30, 2017, with no change in net income, of the following for the Registrant Subsidiaries: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Three months ended September 30, 2017 $3,515 $8,585 $778 $356 $43 $1,521 Nine months ended September 30, 2017 $9,995 $20,942 $1,862 $794 ($194 ) $4,778 The retroactive effect of the change for the years ended December 31, 2017, 2016, and 2015 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $101 million , $71 million , and $148 million , respectively, for Entergy. The retroactive effect of the change for the years ended December 31, 2017, 2016, and 2015 would be decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income, with no change in net income, of the following for the Registrant Subsidiaries: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) For the Year Ended December 31, 2017 $13,668 $27,796 $2,742 $1,293 $179 $6,190 For the Year Ended $13,392 $26,118 $2,424 $1,014 ($1,054 ) $5,088 For the Year Ended $30,671 $50,686 $6,268 $3,975 $4,000 $10,213 Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $116,256 $100,230 Interest cost on projected benefit obligation 200,562 195,618 Expected return on assets (331,605 ) (306,168 ) Amortization of prior service cost 297 195 Amortization of loss 205,578 170,790 Net pension costs $191,088 $160,665 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 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 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projects benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,270 $20,775 $4,416 $1,875 $4,092 $4,608 Interest cost on projected benefit obligation 38,832 44,427 11,196 5,373 10,176 9,273 Expected return on assets (61,281 ) (69,051 ) (18,393 ) (8,400 ) (18,540 ) (13,989 ) Amortization of loss 34,920 37,062 9,159 4,974 6,930 8,892 Net pension cost $27,741 $33,213 $6,378 $3,822 $2,658 $8,784 Non-Qualified Net Pension Cost Entergy recognized $4.2 million and $15.8 million in pension cost for its non-qualified pension plans in the third quarters of 2018 and 2017 , respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2018 and 2017 were settlement charges of $212 thousand and $11.6 million , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $19.7 million and $28.9 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2018 and 2017, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2018 and 2017 were settlement charges of $7 million and $15.5 million , respectively, related to the payment of lump sum benefits out of this plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $114 $42 $73 $20 $122 2017 $111 $46 $62 $18 $124 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarters of 2018 and 2017, were settlement charges of $7 thousand and $10 thousand , 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 nine months ended September 30, 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $369 $138 $230 $62 $529 2017 $483 $141 $189 $55 $377 Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 and 2017, were settlement charges of $30 thousand and $173 thousand , respectively, related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $20,346 $20,187 Interest cost on accumulated postretirement benefit obligation (APBO) 38,043 41,880 Expected return on assets (31,119 ) (28,224 ) Amortization of prior service credit (27,753 ) (31,068 ) Amortization of loss 10,296 16,428 Net other postretirement benefit cost $9,813 $19,203 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,589 $4,779 $870 $426 $1,116 $960 Interest cost on APBO 6,765 9,075 2,070 1,407 3,372 1,677 Expected return on assets (11,877 ) — (3,600 ) (3,477 ) (6,540 ) (2,151 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 3,345 1,395 1,257 315 2,478 1,170 Net other postretirement benefit cost ($3,012 ) $9,447 ($771 ) ($1,887 ) ($1,311 ) $522 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($71 ) $5,425 Amortization of loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($88 ) $6,565 Amortization of loss (18,451 ) (2,202 ) (827 ) (21,480 ) Settlement loss — — (4,200 ) (4,200 ) ($18,516 ) $4,516 ($5,115 ) ($19,115 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($297 ) $16,786 ($211 ) $16,278 Amortization of loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($195 ) $20,152 ($266 ) $19,691 Amortization of loss (55,351 ) (6,606 ) (2,648 ) (64,605 ) Settlement loss — — (5,965 ) (5,965 ) ($55,546 ) $13,546 ($8,879 ) ($50,879 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,594 ) (1,395 ) (7 ) (3,996 ) ($2,594 ) $4,407 ($7 ) $1,806 Employer Contributions Based on current assumptions, Entergy expects to contribute $383.5 million to its qualified pension plans in 2018. As of September 30, 2018 , Entergy had contributed $315.6 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 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,919 $14,933 $7,250 $10,883 $13,786 Pension contributions made through September 2018 $51,982 $58,363 $12,203 $5,938 $9,323 $11,152 Remaining estimated pension contributions to be made in 2018 $12,080 $13,556 $2,730 $1,312 $1,560 $2,634
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) Entergy implemented ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” effective January 1, 2018. The ASU requires entities to report the service cost component of defined benefit pension cost and postretirement benefit cost (net benefit cost) in the same line item as other compensation costs arising from services rendered during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. The amendment regarding the presentation of net benefit cost was required to be applied retrospectively for all periods presented. In addition, the ASU allows only the service cost component of net benefit cost to be eligible for capitalization on a prospective basis. In accordance with the regulatory treatment of net benefit cost of the Registrant Subsidiaries, a regulatory asset/liability will be recorded in other regulatory assets/liabilities for the non-service cost components of net benefit cost that would have been capitalized. The retroactive presentation changes resulted in decreases in other operation and maintenance expenses and decreases in other income for the three months ended September 30, 2017, with no change in net income, of $30 million for Entergy. The retroactive presentation changes resulted in decreases in other operation and maintenance expenses and decreases in other income for the nine months ended September 30, 2017, with no change in net income, of $76 million for Entergy. The retroactive presentation changes resulted in decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income for the three months ended September 30, 2017 and for the nine months ended September 30, 2017, with no change in net income, of the following for the Registrant Subsidiaries: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Three months ended September 30, 2017 $3,515 $8,585 $778 $356 $43 $1,521 Nine months ended September 30, 2017 $9,995 $20,942 $1,862 $794 ($194 ) $4,778 The retroactive effect of the change for the years ended December 31, 2017, 2016, and 2015 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $101 million , $71 million , and $148 million , respectively, for Entergy. The retroactive effect of the change for the years ended December 31, 2017, 2016, and 2015 would be decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income, with no change in net income, of the following for the Registrant Subsidiaries: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) For the Year Ended December 31, 2017 $13,668 $27,796 $2,742 $1,293 $179 $6,190 For the Year Ended $13,392 $26,118 $2,424 $1,014 ($1,054 ) $5,088 For the Year Ended $30,671 $50,686 $6,268 $3,975 $4,000 $10,213 Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $116,256 $100,230 Interest cost on projected benefit obligation 200,562 195,618 Expected return on assets (331,605 ) (306,168 ) Amortization of prior service cost 297 195 Amortization of loss 205,578 170,790 Net pension costs $191,088 $160,665 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 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 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projects benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,270 $20,775 $4,416 $1,875 $4,092 $4,608 Interest cost on projected benefit obligation 38,832 44,427 11,196 5,373 10,176 9,273 Expected return on assets (61,281 ) (69,051 ) (18,393 ) (8,400 ) (18,540 ) (13,989 ) Amortization of loss 34,920 37,062 9,159 4,974 6,930 8,892 Net pension cost $27,741 $33,213 $6,378 $3,822 $2,658 $8,784 Non-Qualified Net Pension Cost Entergy recognized $4.2 million and $15.8 million in pension cost for its non-qualified pension plans in the third quarters of 2018 and 2017 , respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2018 and 2017 were settlement charges of $212 thousand and $11.6 million , respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $19.7 million and $28.9 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2018 and 2017, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2018 and 2017 were settlement charges of $7 million and $15.5 million , respectively, related to the payment of lump sum benefits out of this plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $114 $42 $73 $20 $122 2017 $111 $46 $62 $18 $124 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarters of 2018 and 2017, were settlement charges of $7 thousand and $10 thousand , 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 nine months ended September 30, 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $369 $138 $230 $62 $529 2017 $483 $141 $189 $55 $377 Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 and 2017, were settlement charges of $30 thousand and $173 thousand , respectively, related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $20,346 $20,187 Interest cost on accumulated postretirement benefit obligation (APBO) 38,043 41,880 Expected return on assets (31,119 ) (28,224 ) Amortization of prior service credit (27,753 ) (31,068 ) Amortization of loss 10,296 16,428 Net other postretirement benefit cost $9,813 $19,203 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,589 $4,779 $870 $426 $1,116 $960 Interest cost on APBO 6,765 9,075 2,070 1,407 3,372 1,677 Expected return on assets (11,877 ) — (3,600 ) (3,477 ) (6,540 ) (2,151 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 3,345 1,395 1,257 315 2,478 1,170 Net other postretirement benefit cost ($3,012 ) $9,447 ($771 ) ($1,887 ) ($1,311 ) $522 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($71 ) $5,425 Amortization of loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($88 ) $6,565 Amortization of loss (18,451 ) (2,202 ) (827 ) (21,480 ) Settlement loss — — (4,200 ) (4,200 ) ($18,516 ) $4,516 ($5,115 ) ($19,115 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($297 ) $16,786 ($211 ) $16,278 Amortization of loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($195 ) $20,152 ($266 ) $19,691 Amortization of loss (55,351 ) (6,606 ) (2,648 ) (64,605 ) Settlement loss — — (5,965 ) (5,965 ) ($55,546 ) $13,546 ($8,879 ) ($50,879 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,594 ) (1,395 ) (7 ) (3,996 ) ($2,594 ) $4,407 ($7 ) $1,806 Employer Contributions Based on current assumptions, Entergy expects to contribute $383.5 million to its qualified pension plans in 2018. As of September 30, 2018 , Entergy had contributed $315.6 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 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,919 $14,933 $7,250 $10,883 $13,786 Pension contributions made through September 2018 $51,982 $58,363 $12,203 $5,938 $9,323 $11,152 Remaining estimated pension contributions to be made in 2018 $12,080 $13,556 $2,730 $1,312 $1,560 $2,634

Business Segment Information

Business Segment Information	9 Months Ended
	Sep. 30, 2018
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of September 30, 2018 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. 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 provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 2017 Operating revenues $2,820,421 $423,245 $— ($38 ) $3,243,628 Income taxes $230,647 $25,563 ($14,415 ) $— $241,795 Consolidated net income (loss) $403,733 $55,765 ($25,956 ) ($31,898 ) $401,644 Entergy’s segment financial information for the nine months ended September 30, 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of September 30, 2018 $44,889,498 $5,507,013 $1,274,909 ($3,200,248 ) $48,471,172 2017 Operating revenues $7,156,865 $1,293,867 $— ($96 ) $8,450,636 Income taxes $459,990 ($507,719 ) ($39,826 ) $— ($87,555 ) Consolidated net income (loss) $817,738 $252,455 ($73,434 ) ($95,695 ) $901,064 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149 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 reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the third quarters of 2018 and 2017 were comprised of the following: 2018 2017 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $143 $14 $157 $36 $21 $57 Restructuring costs accrued 43 — 43 23 — 23 Non-cash portion — — — — (7 ) (7 ) Balance as of September 30, $186 $14 $200 $59 $14 $73 In addition, Entergy incurred $155 million in the third quarter 2018 and $16 million in the third quarter 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Total restructuring charges for the nine months ended September 30, 2018 and 2017 were comprised of the following: 2018 2017 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, $83 $14 $97 $70 $21 $91 Restructuring costs accrued 103 — 103 89 — 89 Non-cash portion — — — — (7 ) (7 ) Cash paid out — — — 100 — 100 Balance as of September 30, $186 $14 $200 $59 $14 $73 In addition, Entergy incurred $297 million in the nine months ended September 30, 2018 and $422 million in the nine months ended September 30, 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet of approximately $155 million in 2018, of which $103 million has been incurred as of September 30, 2018, and a total of approximately $215 million from 2019 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 September 30, 2018 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. 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 provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 2017 Operating revenues $2,820,421 $423,245 $— ($38 ) $3,243,628 Income taxes $230,647 $25,563 ($14,415 ) $— $241,795 Consolidated net income (loss) $403,733 $55,765 ($25,956 ) ($31,898 ) $401,644 Entergy’s segment financial information for the nine months ended September 30, 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of September 30, 2018 $44,889,498 $5,507,013 $1,274,909 ($3,200,248 ) $48,471,172 2017 Operating revenues $7,156,865 $1,293,867 $— ($96 ) $8,450,636 Income taxes $459,990 ($507,719 ) ($39,826 ) $— ($87,555 ) Consolidated net income (loss) $817,738 $252,455 ($73,434 ) ($95,695 ) $901,064 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149 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 reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the third quarters of 2018 and 2017 were comprised of the following: 2018 2017 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $143 $14 $157 $36 $21 $57 Restructuring costs accrued 43 — 43 23 — 23 Non-cash portion — — — — (7 ) (7 ) Balance as of September 30, $186 $14 $200 $59 $14 $73 In addition, Entergy incurred $155 million in the third quarter 2018 and $16 million in the third quarter 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Total restructuring charges for the nine months ended September 30, 2018 and 2017 were comprised of the following: 2018 2017 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, $83 $14 $97 $70 $21 $91 Restructuring costs accrued 103 — 103 89 — 89 Non-cash portion — — — — (7 ) (7 ) Cash paid out — — — 100 — 100 Balance as of September 30, $186 $14 $200 $59 $14 $73 In addition, Entergy incurred $297 million in the nine months ended September 30, 2018 and $422 million in the nine months ended September 30, 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet of approximately $155 million in 2018, of which $103 million has been incurred as of September 30, 2018, and a total of approximately $215 million from 2019 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 September 30, 2018 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. 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 provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 2017 Operating revenues $2,820,421 $423,245 $— ($38 ) $3,243,628 Income taxes $230,647 $25,563 ($14,415 ) $— $241,795 Consolidated net income (loss) $403,733 $55,765 ($25,956 ) ($31,898 ) $401,644 Entergy’s segment financial information for the nine months ended September 30, 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of September 30, 2018 $44,889,498 $5,507,013 $1,274,909 ($3,200,248 ) $48,471,172 2017 Operating revenues $7,156,865 $1,293,867 $— ($96 ) $8,450,636 Income taxes $459,990 ($507,719 ) ($39,826 ) $— ($87,555 ) Consolidated net income (loss) $817,738 $252,455 ($73,434 ) ($95,695 ) $901,064 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149 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 reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the third quarters of 2018 and 2017 were comprised of the following: 2018 2017 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $143 $14 $157 $36 $21 $57 Restructuring costs accrued 43 — 43 23 — 23 Non-cash portion — — — — (7 ) (7 ) Balance as of September 30, $186 $14 $200 $59 $14 $73 In addition, Entergy incurred $155 million in the third quarter 2018 and $16 million in the third quarter 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Total restructuring charges for the nine months ended September 30, 2018 and 2017 were comprised of the following: 2018 2017 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, $83 $14 $97 $70 $21 $91 Restructuring costs accrued 103 — 103 89 — 89 Non-cash portion — — — — (7 ) (7 ) Cash paid out — — — 100 — 100 Balance as of September 30, $186 $14 $200 $59 $14 $73 In addition, Entergy incurred $297 million in the nine months ended September 30, 2018 and $422 million in the nine months ended September 30, 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet of approximately $155 million in 2018, of which $103 million has been incurred as of September 30, 2018, and a total of approximately $215 million from 2019 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 September 30, 2018 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. 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 provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 2017 Operating revenues $2,820,421 $423,245 $— ($38 ) $3,243,628 Income taxes $230,647 $25,563 ($14,415 ) $— $241,795 Consolidated net income (loss) $403,733 $55,765 ($25,956 ) ($31,898 ) $401,644 Entergy’s segment financial information for the nine months ended September 30, 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of September 30, 2018 $44,889,498 $5,507,013 $1,274,909 ($3,200,248 ) $48,471,172 2017 Operating revenues $7,156,865 $1,293,867 $— ($96 ) $8,450,636 Income taxes $459,990 ($507,719 ) ($39,826 ) $— ($87,555 ) Consolidated net income (loss) $817,738 $252,455 ($73,434 ) ($95,695 ) $901,064 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149 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 reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the third quarters of 2018 and 2017 were comprised of the following: 2018 2017 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $143 $14 $157 $36 $21 $57 Restructuring costs accrued 43 — 43 23 — 23 Non-cash portion — — — — (7 ) (7 ) Balance as of September 30, $186 $14 $200 $59 $14 $73 In addition, Entergy incurred $155 million in the third quarter 2018 and $16 million in the third quarter 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Total restructuring charges for the nine months ended September 30, 2018 and 2017 were comprised of the following: 2018 2017 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, $83 $14 $97 $70 $21 $91 Restructuring costs accrued 103 — 103 89 — 89 Non-cash portion — — — — (7 ) (7 ) Cash paid out — — — 100 — 100 Balance as of September 30, $186 $14 $200 $59 $14 $73 In addition, Entergy incurred $297 million in the nine months ended September 30, 2018 and $422 million in the nine months ended September 30, 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet of approximately $155 million in 2018, of which $103 million has been incurred as of September 30, 2018, and a total of approximately $215 million from 2019 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 September 30, 2018 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. 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 provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 2017 Operating revenues $2,820,421 $423,245 $— ($38 ) $3,243,628 Income taxes $230,647 $25,563 ($14,415 ) $— $241,795 Consolidated net income (loss) $403,733 $55,765 ($25,956 ) ($31,898 ) $401,644 Entergy’s segment financial information for the nine months ended September 30, 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of September 30, 2018 $44,889,498 $5,507,013 $1,274,909 ($3,200,248 ) $48,471,172 2017 Operating revenues $7,156,865 $1,293,867 $— ($96 ) $8,450,636 Income taxes $459,990 ($507,719 ) ($39,826 ) $— ($87,555 ) Consolidated net income (loss) $817,738 $252,455 ($73,434 ) ($95,695 ) $901,064 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149 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 reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the third quarters of 2018 and 2017 were comprised of the following: 2018 2017 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $143 $14 $157 $36 $21 $57 Restructuring costs accrued 43 — 43 23 — 23 Non-cash portion — — — — (7 ) (7 ) Balance as of September 30, $186 $14 $200 $59 $14 $73 In addition, Entergy incurred $155 million in the third quarter 2018 and $16 million in the third quarter 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Total restructuring charges for the nine months ended September 30, 2018 and 2017 were comprised of the following: 2018 2017 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, $83 $14 $97 $70 $21 $91 Restructuring costs accrued 103 — 103 89 — 89 Non-cash portion — — — — (7 ) (7 ) Cash paid out — — — 100 — 100 Balance as of September 30, $186 $14 $200 $59 $14 $73 In addition, Entergy incurred $297 million in the nine months ended September 30, 2018 and $422 million in the nine months ended September 30, 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet of approximately $155 million in 2018, of which $103 million has been incurred as of September 30, 2018, and a total of approximately $215 million from 2019 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 September 30, 2018 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. 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 provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 2017 Operating revenues $2,820,421 $423,245 $— ($38 ) $3,243,628 Income taxes $230,647 $25,563 ($14,415 ) $— $241,795 Consolidated net income (loss) $403,733 $55,765 ($25,956 ) ($31,898 ) $401,644 Entergy’s segment financial information for the nine months ended September 30, 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of September 30, 2018 $44,889,498 $5,507,013 $1,274,909 ($3,200,248 ) $48,471,172 2017 Operating revenues $7,156,865 $1,293,867 $— ($96 ) $8,450,636 Income taxes $459,990 ($507,719 ) ($39,826 ) $— ($87,555 ) Consolidated net income (loss) $817,738 $252,455 ($73,434 ) ($95,695 ) $901,064 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149 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 reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the third quarters of 2018 and 2017 were comprised of the following: 2018 2017 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $143 $14 $157 $36 $21 $57 Restructuring costs accrued 43 — 43 23 — 23 Non-cash portion — — — — (7 ) (7 ) Balance as of September 30, $186 $14 $200 $59 $14 $73 In addition, Entergy incurred $155 million in the third quarter 2018 and $16 million in the third quarter 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Total restructuring charges for the nine months ended September 30, 2018 and 2017 were comprised of the following: 2018 2017 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, $83 $14 $97 $70 $21 $91 Restructuring costs accrued 103 — 103 89 — 89 Non-cash portion — — — — (7 ) (7 ) Cash paid out — — — 100 — 100 Balance as of September 30, $186 $14 $200 $59 $14 $73 In addition, Entergy incurred $297 million in the nine months ended September 30, 2018 and $422 million in the nine months ended September 30, 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet of approximately $155 million in 2018, of which $103 million has been incurred as of September 30, 2018, and a total of approximately $215 million from 2019 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 September 30, 2018 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. 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 provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 2017 Operating revenues $2,820,421 $423,245 $— ($38 ) $3,243,628 Income taxes $230,647 $25,563 ($14,415 ) $— $241,795 Consolidated net income (loss) $403,733 $55,765 ($25,956 ) ($31,898 ) $401,644 Entergy’s segment financial information for the nine months ended September 30, 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of September 30, 2018 $44,889,498 $5,507,013 $1,274,909 ($3,200,248 ) $48,471,172 2017 Operating revenues $7,156,865 $1,293,867 $— ($96 ) $8,450,636 Income taxes $459,990 ($507,719 ) ($39,826 ) $— ($87,555 ) Consolidated net income (loss) $817,738 $252,455 ($73,434 ) ($95,695 ) $901,064 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149 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 reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the third quarters of 2018 and 2017 were comprised of the following: 2018 2017 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $143 $14 $157 $36 $21 $57 Restructuring costs accrued 43 — 43 23 — 23 Non-cash portion — — — — (7 ) (7 ) Balance as of September 30, $186 $14 $200 $59 $14 $73 In addition, Entergy incurred $155 million in the third quarter 2018 and $16 million in the third quarter 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Total restructuring charges for the nine months ended September 30, 2018 and 2017 were comprised of the following: 2018 2017 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, $83 $14 $97 $70 $21 $91 Restructuring costs accrued 103 — 103 89 — 89 Non-cash portion — — — — (7 ) (7 ) Cash paid out — — — 100 — 100 Balance as of September 30, $186 $14 $200 $59 $14 $73 In addition, Entergy incurred $297 million in the nine months ended September 30, 2018 and $422 million in the nine months ended September 30, 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet of approximately $155 million in 2018, of which $103 million has been incurred as of September 30, 2018, and a total of approximately $215 million from 2019 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	9 Months Ended
	Sep. 30, 2018
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2018 is approximately 2.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2018 , of which approximately 87% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2018 is 6.7 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 guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of September 30, 2018 , derivative contracts with seven counterparties were in a liability position (approximately $68 million total). In addition to the corporate guarantee, $30 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2017 , derivative contracts with eight counterparties were in a liability position (approximately $65 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $4 million in cash collateral and $34 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. 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 short-term natural gas swaps that financially settle against NYMEX futures. These swaps 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 for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of September 30, 2018 is 13,814,000 MMBtu for Entergy, including 6,300,000 MMBtu for Entergy Louisiana, 6,790,000 MMBtu for Entergy Mississippi, and 724,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2018, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2018 through May 31, 2019. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2018 is 77,520 GWh for Entergy, including 17,557 GWh for Entergy Arkansas, 33,144 GWh for Entergy Louisiana, 10,295 GWh for Entergy Mississippi, 3,758 GWh for Entergy New Orleans, and 12,441 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2018 and December 31, 2017. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Mississippi, and Entergy Texas as of September 30, 2018 and December 31, 2017, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $10 ($10) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $62 ($10) $52 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $24 ($11) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $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 $4 ($3) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Entergy Wholesale Commodities The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 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 $30 million posted as of September 30, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes letters of credit in the amount of $5 million posted as of September 30, 2018 and $34 million in letters of credit held as of December 31, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $23 (a) Before taxes of ($2) million and $8 million for the three months ended September 30, 2018 and 2017, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) 2017 Electricity swaps and options $136 Competitive businesses operating revenues $87 (a) Before taxes of ($8) million and $30 million for the nine months ended September 30, 2018 and 2017, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 and 2017 was ($3.1) million and $2.4 million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 and 2017 was ($5.2) million and $6.4 million , respectively. Based on market prices as of September 30, 2018 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled ($58) million of net unrealized losses. Approximately ($47) million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights $— Purchased power expense (b) $28 Electricity swaps and options ($2) (c) Competitive business operating revenues $— The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($20) Financial transmission rights $— Purchased power expense (b) $103 Electricity swaps and options $2 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps 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 are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2018 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $1.0 $— $1.0 Entergy Louisiana Natural gas swaps Prepayments and other $0.4 $— $0.4 Entergy Mississippi Financial transmission rights Prepayments and other $11.6 ($0.3) $11.3 Entergy Arkansas Financial transmission rights Prepayments and other $12.2 ($0.2) $12.0 Entergy Louisiana Financial transmission rights Prepayments and other $3.7 $— $3.7 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($1.6) $0.1 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.6) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.2 (b) Entergy Arkansas Financial transmission rights Purchased power expense $9.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.0 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.1) (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 $19.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $38.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $16.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $7.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $19.2 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps 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 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 hedge contracts. 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. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options a
Entergy Arkansas [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2018 is approximately 2.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2018 , of which approximately 87% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2018 is 6.7 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 guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of September 30, 2018 , derivative contracts with seven counterparties were in a liability position (approximately $68 million total). In addition to the corporate guarantee, $30 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2017 , derivative contracts with eight counterparties were in a liability position (approximately $65 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $4 million in cash collateral and $34 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. 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 short-term natural gas swaps that financially settle against NYMEX futures. These swaps 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 for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of September 30, 2018 is 13,814,000 MMBtu for Entergy, including 6,300,000 MMBtu for Entergy Louisiana, 6,790,000 MMBtu for Entergy Mississippi, and 724,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2018, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2018 through May 31, 2019. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2018 is 77,520 GWh for Entergy, including 17,557 GWh for Entergy Arkansas, 33,144 GWh for Entergy Louisiana, 10,295 GWh for Entergy Mississippi, 3,758 GWh for Entergy New Orleans, and 12,441 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2018 and December 31, 2017. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Mississippi, and Entergy Texas as of September 30, 2018 and December 31, 2017, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $10 ($10) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $62 ($10) $52 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $24 ($11) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $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 $4 ($3) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Entergy Wholesale Commodities The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 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 $30 million posted as of September 30, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes letters of credit in the amount of $5 million posted as of September 30, 2018 and $34 million in letters of credit held as of December 31, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $23 (a) Before taxes of ($2) million and $8 million for the three months ended September 30, 2018 and 2017, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) 2017 Electricity swaps and options $136 Competitive businesses operating revenues $87 (a) Before taxes of ($8) million and $30 million for the nine months ended September 30, 2018 and 2017, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 and 2017 was ($3.1) million and $2.4 million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 and 2017 was ($5.2) million and $6.4 million , respectively. Based on market prices as of September 30, 2018 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled ($58) million of net unrealized losses. Approximately ($47) million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights $— Purchased power expense (b) $28 Electricity swaps and options ($2) (c) Competitive business operating revenues $— The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($20) Financial transmission rights $— Purchased power expense (b) $103 Electricity swaps and options $2 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps 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 are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2018 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $1.0 $— $1.0 Entergy Louisiana Natural gas swaps Prepayments and other $0.4 $— $0.4 Entergy Mississippi Financial transmission rights Prepayments and other $11.6 ($0.3) $11.3 Entergy Arkansas Financial transmission rights Prepayments and other $12.2 ($0.2) $12.0 Entergy Louisiana Financial transmission rights Prepayments and other $3.7 $— $3.7 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($1.6) $0.1 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.6) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.2 (b) Entergy Arkansas Financial transmission rights Purchased power expense $9.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.0 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.1) (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 $19.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $38.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $16.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $7.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $19.2 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps 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 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 hedge contracts. 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. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options a
Entergy Louisiana [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2018 is approximately 2.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2018 , of which approximately 87% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2018 is 6.7 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 guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of September 30, 2018 , derivative contracts with seven counterparties were in a liability position (approximately $68 million total). In addition to the corporate guarantee, $30 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2017 , derivative contracts with eight counterparties were in a liability position (approximately $65 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $4 million in cash collateral and $34 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. 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 short-term natural gas swaps that financially settle against NYMEX futures. These swaps 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 for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of September 30, 2018 is 13,814,000 MMBtu for Entergy, including 6,300,000 MMBtu for Entergy Louisiana, 6,790,000 MMBtu for Entergy Mississippi, and 724,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2018, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2018 through May 31, 2019. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2018 is 77,520 GWh for Entergy, including 17,557 GWh for Entergy Arkansas, 33,144 GWh for Entergy Louisiana, 10,295 GWh for Entergy Mississippi, 3,758 GWh for Entergy New Orleans, and 12,441 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2018 and December 31, 2017. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Mississippi, and Entergy Texas as of September 30, 2018 and December 31, 2017, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $10 ($10) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $62 ($10) $52 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $24 ($11) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $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 $4 ($3) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Entergy Wholesale Commodities The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 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 $30 million posted as of September 30, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes letters of credit in the amount of $5 million posted as of September 30, 2018 and $34 million in letters of credit held as of December 31, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $23 (a) Before taxes of ($2) million and $8 million for the three months ended September 30, 2018 and 2017, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) 2017 Electricity swaps and options $136 Competitive businesses operating revenues $87 (a) Before taxes of ($8) million and $30 million for the nine months ended September 30, 2018 and 2017, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 and 2017 was ($3.1) million and $2.4 million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 and 2017 was ($5.2) million and $6.4 million , respectively. Based on market prices as of September 30, 2018 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled ($58) million of net unrealized losses. Approximately ($47) million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights $— Purchased power expense (b) $28 Electricity swaps and options ($2) (c) Competitive business operating revenues $— The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($20) Financial transmission rights $— Purchased power expense (b) $103 Electricity swaps and options $2 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps 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 are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2018 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $1.0 $— $1.0 Entergy Louisiana Natural gas swaps Prepayments and other $0.4 $— $0.4 Entergy Mississippi Financial transmission rights Prepayments and other $11.6 ($0.3) $11.3 Entergy Arkansas Financial transmission rights Prepayments and other $12.2 ($0.2) $12.0 Entergy Louisiana Financial transmission rights Prepayments and other $3.7 $— $3.7 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($1.6) $0.1 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.6) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.2 (b) Entergy Arkansas Financial transmission rights Purchased power expense $9.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.0 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.1) (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 $19.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $38.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $16.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $7.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $19.2 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps 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 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 hedge contracts. 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. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options a
Entergy Mississippi [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2018 is approximately 2.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2018 , of which approximately 87% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2018 is 6.7 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 guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of September 30, 2018 , derivative contracts with seven counterparties were in a liability position (approximately $68 million total). In addition to the corporate guarantee, $30 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2017 , derivative contracts with eight counterparties were in a liability position (approximately $65 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $4 million in cash collateral and $34 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. 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 short-term natural gas swaps that financially settle against NYMEX futures. These swaps 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 for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of September 30, 2018 is 13,814,000 MMBtu for Entergy, including 6,300,000 MMBtu for Entergy Louisiana, 6,790,000 MMBtu for Entergy Mississippi, and 724,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2018, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2018 through May 31, 2019. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2018 is 77,520 GWh for Entergy, including 17,557 GWh for Entergy Arkansas, 33,144 GWh for Entergy Louisiana, 10,295 GWh for Entergy Mississippi, 3,758 GWh for Entergy New Orleans, and 12,441 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2018 and December 31, 2017. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Mississippi, and Entergy Texas as of September 30, 2018 and December 31, 2017, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $10 ($10) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $62 ($10) $52 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $24 ($11) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $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 $4 ($3) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Entergy Wholesale Commodities The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 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 $30 million posted as of September 30, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes letters of credit in the amount of $5 million posted as of September 30, 2018 and $34 million in letters of credit held as of December 31, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $23 (a) Before taxes of ($2) million and $8 million for the three months ended September 30, 2018 and 2017, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) 2017 Electricity swaps and options $136 Competitive businesses operating revenues $87 (a) Before taxes of ($8) million and $30 million for the nine months ended September 30, 2018 and 2017, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 and 2017 was ($3.1) million and $2.4 million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 and 2017 was ($5.2) million and $6.4 million , respectively. Based on market prices as of September 30, 2018 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled ($58) million of net unrealized losses. Approximately ($47) million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights $— Purchased power expense (b) $28 Electricity swaps and options ($2) (c) Competitive business operating revenues $— The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($20) Financial transmission rights $— Purchased power expense (b) $103 Electricity swaps and options $2 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps 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 are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2018 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $1.0 $— $1.0 Entergy Louisiana Natural gas swaps Prepayments and other $0.4 $— $0.4 Entergy Mississippi Financial transmission rights Prepayments and other $11.6 ($0.3) $11.3 Entergy Arkansas Financial transmission rights Prepayments and other $12.2 ($0.2) $12.0 Entergy Louisiana Financial transmission rights Prepayments and other $3.7 $— $3.7 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($1.6) $0.1 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.6) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.2 (b) Entergy Arkansas Financial transmission rights Purchased power expense $9.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.0 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.1) (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 $19.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $38.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $16.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $7.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $19.2 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps 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 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 hedge contracts. 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. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options a
Entergy New Orleans [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2018 is approximately 2.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2018 , of which approximately 87% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2018 is 6.7 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 guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of September 30, 2018 , derivative contracts with seven counterparties were in a liability position (approximately $68 million total). In addition to the corporate guarantee, $30 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2017 , derivative contracts with eight counterparties were in a liability position (approximately $65 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $4 million in cash collateral and $34 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. 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 short-term natural gas swaps that financially settle against NYMEX futures. These swaps 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 for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of September 30, 2018 is 13,814,000 MMBtu for Entergy, including 6,300,000 MMBtu for Entergy Louisiana, 6,790,000 MMBtu for Entergy Mississippi, and 724,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2018, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2018 through May 31, 2019. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2018 is 77,520 GWh for Entergy, including 17,557 GWh for Entergy Arkansas, 33,144 GWh for Entergy Louisiana, 10,295 GWh for Entergy Mississippi, 3,758 GWh for Entergy New Orleans, and 12,441 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2018 and December 31, 2017. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Mississippi, and Entergy Texas as of September 30, 2018 and December 31, 2017, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $10 ($10) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $62 ($10) $52 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $24 ($11) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $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 $4 ($3) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Entergy Wholesale Commodities The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 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 $30 million posted as of September 30, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes letters of credit in the amount of $5 million posted as of September 30, 2018 and $34 million in letters of credit held as of December 31, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $23 (a) Before taxes of ($2) million and $8 million for the three months ended September 30, 2018 and 2017, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) 2017 Electricity swaps and options $136 Competitive businesses operating revenues $87 (a) Before taxes of ($8) million and $30 million for the nine months ended September 30, 2018 and 2017, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 and 2017 was ($3.1) million and $2.4 million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 and 2017 was ($5.2) million and $6.4 million , respectively. Based on market prices as of September 30, 2018 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled ($58) million of net unrealized losses. Approximately ($47) million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights $— Purchased power expense (b) $28 Electricity swaps and options ($2) (c) Competitive business operating revenues $— The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($20) Financial transmission rights $— Purchased power expense (b) $103 Electricity swaps and options $2 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps 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 are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2018 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $1.0 $— $1.0 Entergy Louisiana Natural gas swaps Prepayments and other $0.4 $— $0.4 Entergy Mississippi Financial transmission rights Prepayments and other $11.6 ($0.3) $11.3 Entergy Arkansas Financial transmission rights Prepayments and other $12.2 ($0.2) $12.0 Entergy Louisiana Financial transmission rights Prepayments and other $3.7 $— $3.7 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($1.6) $0.1 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.6) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.2 (b) Entergy Arkansas Financial transmission rights Purchased power expense $9.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.0 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.1) (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 $19.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $38.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $16.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $7.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $19.2 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps 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 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 hedge contracts. 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. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options a
Entergy Texas [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2018 is approximately 2.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2018 , of which approximately 87% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2018 is 6.7 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 guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of September 30, 2018 , derivative contracts with seven counterparties were in a liability position (approximately $68 million total). In addition to the corporate guarantee, $30 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2017 , derivative contracts with eight counterparties were in a liability position (approximately $65 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $4 million in cash collateral and $34 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. 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 short-term natural gas swaps that financially settle against NYMEX futures. These swaps 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 for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of September 30, 2018 is 13,814,000 MMBtu for Entergy, including 6,300,000 MMBtu for Entergy Louisiana, 6,790,000 MMBtu for Entergy Mississippi, and 724,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2018, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2018 through May 31, 2019. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2018 is 77,520 GWh for Entergy, including 17,557 GWh for Entergy Arkansas, 33,144 GWh for Entergy Louisiana, 10,295 GWh for Entergy Mississippi, 3,758 GWh for Entergy New Orleans, and 12,441 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2018 and December 31, 2017. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Mississippi, and Entergy Texas as of September 30, 2018 and December 31, 2017, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $10 ($10) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $62 ($10) $52 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $24 ($11) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $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 $4 ($3) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Entergy Wholesale Commodities The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 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 $30 million posted as of September 30, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes letters of credit in the amount of $5 million posted as of September 30, 2018 and $34 million in letters of credit held as of December 31, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $23 (a) Before taxes of ($2) million and $8 million for the three months ended September 30, 2018 and 2017, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) 2017 Electricity swaps and options $136 Competitive businesses operating revenues $87 (a) Before taxes of ($8) million and $30 million for the nine months ended September 30, 2018 and 2017, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 and 2017 was ($3.1) million and $2.4 million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 and 2017 was ($5.2) million and $6.4 million , respectively. Based on market prices as of September 30, 2018 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled ($58) million of net unrealized losses. Approximately ($47) million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights $— Purchased power expense (b) $28 Electricity swaps and options ($2) (c) Competitive business operating revenues $— The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($20) Financial transmission rights $— Purchased power expense (b) $103 Electricity swaps and options $2 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps 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 are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2018 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $1.0 $— $1.0 Entergy Louisiana Natural gas swaps Prepayments and other $0.4 $— $0.4 Entergy Mississippi Financial transmission rights Prepayments and other $11.6 ($0.3) $11.3 Entergy Arkansas Financial transmission rights Prepayments and other $12.2 ($0.2) $12.0 Entergy Louisiana Financial transmission rights Prepayments and other $3.7 $— $3.7 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($1.6) $0.1 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.6) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.2 (b) Entergy Arkansas Financial transmission rights Purchased power expense $9.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.0 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.1) (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 $19.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $38.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $16.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $7.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $19.2 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps 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 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 hedge contracts. 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. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options a
System Energy [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2018 is approximately 2.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2018 , of which approximately 87% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2018 is 6.7 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 guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of September 30, 2018 , derivative contracts with seven counterparties were in a liability position (approximately $68 million total). In addition to the corporate guarantee, $30 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2017 , derivative contracts with eight counterparties were in a liability position (approximately $65 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $4 million in cash collateral and $34 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. 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 short-term natural gas swaps that financially settle against NYMEX futures. These swaps 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 for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of September 30, 2018 is 13,814,000 MMBtu for Entergy, including 6,300,000 MMBtu for Entergy Louisiana, 6,790,000 MMBtu for Entergy Mississippi, and 724,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2018, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2018 through May 31, 2019. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2018 is 77,520 GWh for Entergy, including 17,557 GWh for Entergy Arkansas, 33,144 GWh for Entergy Louisiana, 10,295 GWh for Entergy Mississippi, 3,758 GWh for Entergy New Orleans, and 12,441 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2018 and December 31, 2017. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Mississippi, and Entergy Texas as of September 30, 2018 and December 31, 2017, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $10 ($10) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $62 ($10) $52 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $24 ($11) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $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 $4 ($3) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Entergy Wholesale Commodities The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 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 $30 million posted as of September 30, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes letters of credit in the amount of $5 million posted as of September 30, 2018 and $34 million in letters of credit held as of December 31, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $23 (a) Before taxes of ($2) million and $8 million for the three months ended September 30, 2018 and 2017, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) 2017 Electricity swaps and options $136 Competitive businesses operating revenues $87 (a) Before taxes of ($8) million and $30 million for the nine months ended September 30, 2018 and 2017, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 and 2017 was ($3.1) million and $2.4 million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 and 2017 was ($5.2) million and $6.4 million , respectively. Based on market prices as of September 30, 2018 , unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled ($58) million of net unrealized losses. Approximately ($47) million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights $— Purchased power expense (b) $28 Electricity swaps and options ($2) (c) Competitive business operating revenues $— The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($20) Financial transmission rights $— Purchased power expense (b) $103 Electricity swaps and options $2 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps 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 are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2018 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $1.0 $— $1.0 Entergy Louisiana Natural gas swaps Prepayments and other $0.4 $— $0.4 Entergy Mississippi Financial transmission rights Prepayments and other $11.6 ($0.3) $11.3 Entergy Arkansas Financial transmission rights Prepayments and other $12.2 ($0.2) $12.0 Entergy Louisiana Financial transmission rights Prepayments and other $3.7 $— $3.7 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($1.6) $0.1 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.6) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.2 (b) Entergy Arkansas Financial transmission rights Purchased power expense $9.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.0 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.1) (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 $19.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $38.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $16.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $7.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $19.2 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps 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 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 hedge contracts. 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. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options a

Decommissioning Trust Funds

Decommissioning Trust Funds	9 Months Ended
	Sep. 30, 2018
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, Vermont Yankee, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. Entergy implemented ASU No. 2016-01 “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” effective January 1, 2018. The ASU requires investments in equity securities, excluding those accounted for under the equity method or resulting in consolidation of the investee, to be measured at fair value with changes recognized in net income. Entergy implemented this ASU using a modified retrospective method, and Entergy recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by $633 million as of January 1, 2018, for the cumulative effect of the unrealized gains and losses on investments in equity securities held by the decommissioning trust funds that do not meet the criteria for regulatory accounting treatment. Beginning in 2018, unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds will be recorded in earnings as they occur rather than in other comprehensive income. In accordance with the regulatory treatment of the decommissioning trust funds of the Registrant Subsidiaries, an offsetting amount of unrealized gains/(losses) will continue to be recorded in other regulatory liabilities/assets. 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, Vermont Yankee, and Palisades do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds are held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company are recognized in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $369 million and $464 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 available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities (a) $2,448 $10 $51 2017 Equity Securities $4,662 $2,131 $1 Debt Securities 2,550 44 16 Total $7,212 $2,175 $17 (a) Debt securities presented herein do not include the $397 million of debt securities held in the wholly-owned registered investment company, which are not accounted for as available-for-sale. The unrealized gains/(losses) above are reported before deferred taxes of $472 million as of December 31, 2017 for equity securities, and ($6) million as of September 30, 2018 and $7 million as of December 31, 2017 for debt securities. The amortized cost of available-for-sale debt securities was $2,489 million as of September 30, 2018 and $2,539 million as of December 31, 2017 . As of September 30, 2018 , available-for-sale debt securities have an average coupon rate of approximately 3.36% , an average duration of approximately 5.98 years, and an average maturity of approximately 10.4 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1,691 $33 More than 12 months 357 18 Total $2,048 $51 The fair value and gross unrealized losses of available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8 $1 $1,099 $7 More than 12 months — — 265 9 Total $8 $1 $1,364 $16 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $119 $74 1 year - 5 years 934 902 5 years - 10 years 628 812 10 years - 15 years 108 147 15 years - 20 years 92 100 20 years+ 567 515 Total $2,448 $2,550 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $2,377 million and $440 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $4 million and $9 million , respectively, and gross losses of $15 million and $2 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $4,178 million and $1,903 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $6 million and $79 million , respectively, and gross losses of $37 million and $9 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of September 30, 2018 are $509 million for Indian Point 1, $644 million for Indian Point 2, $835 million for Indian Point 3, $476 million for Palisades, $1,081 million for Pilgrim, and $554 million for Vermont Yankee. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2017 are $491 million for Indian Point 1, $621 million for Indian Point 2, $798 million for Indian Point 3, $458 million for Palisades, $1,068 million for Pilgrim, and $613 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities $378.5 $0.2 $10.9 2017 Equity Securities $596.7 $354.9 $— Debt Securities 348.2 2.1 3.0 Total $944.9 $357.0 $3.0 The amortized cost of available-for-sale debt securities was $389.2 million as of September 30, 2018 and $349.1 million as of December 31, 2017 . As of September 30, 2018 , available-for-sale debt securities have an average coupon rate of approximately 2.68% , an average duration of approximately 4.6 years, and an average maturity of approximately 6.47 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $37.8 million and $46 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 investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $259.7 $6.8 More than 12 months 78.2 4.1 Total $337.9 $10.9 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $168.0 $1.2 More than 12 months — — 41.4 1.8 Total $— $— $209.4 $3.0 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $40.8 $13.0 1 year - 5 years 174.4 123.4 5 years - 10 years 115.6 180.6 10 years - 15 years 10.6 4.8 15 years - 20 years 5.8 3.4 20 years+ 31.3 23.0 Total $378.5 $348.2 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $137.9 million and $51.9 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $0.01 million and $0.04 million , respectively, and gross losses of $0.6 million and $0.5 thousand , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $259.3 million and $219.2 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $0.1 million and $11.7 million , respectively, and gross losses of $3 million and $0.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities $520.5 $2.0 $9.3 2017 Equity Securities $818.3 $461.2 $— Debt Securities 493.8 10.9 3.6 Total $1,312.1 $472.1 $3.6 The amortized cost of available-for-sale debt securities was $527.8 million as of September 30, 2018 and $490 million as of December 31, 2017 . As of September 30, 2018 , the available-for-sale debt securities have an average coupon rate of approximately 4.07% , an average duration of approximately 6.74 years, and an average maturity of approximately 13.75 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $55 million and $66.3 million , respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $355.6 $5.8 More than 12 months 74.0 3.5 Total $429.6 $9.3 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $135.3 $1.1 More than 12 months — — 84.4 2.5 Total $— $— $219.7 $3.6 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $22.4 $23.2 1 year - 5 years 122.0 122.8 5 years - 10 years 117.9 109.3 10 years - 15 years 37.7 52.7 15 years - 20 years 41.3 50.7 20 years+ 179.2 135.1 Total $520.5 $493.8 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $773.9 million and $50.5 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $1.9 million and $2.9 million , respectively, and gross losses of $3.6 million and $0.1 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $943.3 million and $176.1 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $2.5 million and $7.9 million , respectively, and gross losses of $4.8 million and $0.4 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities $359.2 $0.9 $7.1 2017 Equity Securities $575.2 $308.6 $— Debt Securities 330.5 4.2 1.2 Total $905.7 $312.8 $1.2 The amortized cost of available-for-sale debt securities was $365.5 million as of September 30, 2018 and $327.5 million as of December 31, 2017 . As of September 30, 2018 , available-for-sale debt securities have an average coupon rate of approximately 2.95% , an average duration of approximately 6.2 years, and an average maturity of approximately 9.08 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $35.9 million and $43.8 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 investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $267.6 $5.2 More than 12 months 34.3 1.9 Total $301.9 $7.1 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $196.9 $1.0 More than 12 months — — 10.4 0.2 Total $— $— $207.3 $1.2 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $2.2 $4.1 1 year - 5 years 195.4 173.0 5 years - 10 years 78.2 78.5 10 years - 15 years 5.6 1.0 15 years - 20 years 11.0 6.9 20 years+ 66.8 67.0 Total $359.2 $330.5 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $157.8 million and $54.6 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $6.5 thousand and $0.2 million , respectively, and gross losses of $0.3 million and $0.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $357.2 million and $308.1 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $0.3 million and $0.7 million , respectively, and gross losses of $4.8 million and $1.5 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 nine months ended September 30, 2018 and 2017 . Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.
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, Vermont Yankee, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. Entergy implemented ASU No. 2016-01 “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” effective January 1, 2018. The ASU requires investments in equity securities, excluding those accounted for under the equity method or resulting in consolidation of the investee, to be measured at fair value with changes recognized in net income. Entergy implemented this ASU using a modified retrospective method, and Entergy recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by $633 million as of January 1, 2018, for the cumulative effect of the unrealized gains and losses on investments in equity securities held by the decommissioning trust funds that do not meet the criteria for regulatory accounting treatment. Beginning in 2018, unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds will be recorded in earnings as they occur rather than in other comprehensive income. In accordance with the regulatory treatment of the decommissioning trust funds of the Registrant Subsidiaries, an offsetting amount of unrealized gains/(losses) will continue to be recorded in other regulatory liabilities/assets. 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, Vermont Yankee, and Palisades do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds are held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company are recognized in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $369 million and $464 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 available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities (a) $2,448 $10 $51 2017 Equity Securities $4,662 $2,131 $1 Debt Securities 2,550 44 16 Total $7,212 $2,175 $17 (a) Debt securities presented herein do not include the $397 million of debt securities held in the wholly-owned registered investment company, which are not accounted for as available-for-sale. The unrealized gains/(losses) above are reported before deferred taxes of $472 million as of December 31, 2017 for equity securities, and ($6) million as of September 30, 2018 and $7 million as of December 31, 2017 for debt securities. The amortized cost of available-for-sale debt securities was $2,489 million as of September 30, 2018 and $2,539 million as of December 31, 2017 . As of September 30, 2018 , available-for-sale debt securities have an average coupon rate of approximately 3.36% , an average duration of approximately 5.98 years, and an average maturity of approximately 10.4 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1,691 $33 More than 12 months 357 18 Total $2,048 $51 The fair value and gross unrealized losses of available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8 $1 $1,099 $7 More than 12 months — — 265 9 Total $8 $1 $1,364 $16 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $119 $74 1 year - 5 years 934 902 5 years - 10 years 628 812 10 years - 15 years 108 147 15 years - 20 years 92 100 20 years+ 567 515 Total $2,448 $2,550 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $2,377 million and $440 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $4 million and $9 million , respectively, and gross losses of $15 million and $2 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $4,178 million and $1,903 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $6 million and $79 million , respectively, and gross losses of $37 million and $9 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of September 30, 2018 are $509 million for Indian Point 1, $644 million for Indian Point 2, $835 million for Indian Point 3, $476 million for Palisades, $1,081 million for Pilgrim, and $554 million for Vermont Yankee. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2017 are $491 million for Indian Point 1, $621 million for Indian Point 2, $798 million for Indian Point 3, $458 million for Palisades, $1,068 million for Pilgrim, and $613 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities $378.5 $0.2 $10.9 2017 Equity Securities $596.7 $354.9 $— Debt Securities 348.2 2.1 3.0 Total $944.9 $357.0 $3.0 The amortized cost of available-for-sale debt securities was $389.2 million as of September 30, 2018 and $349.1 million as of December 31, 2017 . As of September 30, 2018 , available-for-sale debt securities have an average coupon rate of approximately 2.68% , an average duration of approximately 4.6 years, and an average maturity of approximately 6.47 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $37.8 million and $46 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 investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $259.7 $6.8 More than 12 months 78.2 4.1 Total $337.9 $10.9 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $168.0 $1.2 More than 12 months — — 41.4 1.8 Total $— $— $209.4 $3.0 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $40.8 $13.0 1 year - 5 years 174.4 123.4 5 years - 10 years 115.6 180.6 10 years - 15 years 10.6 4.8 15 years - 20 years 5.8 3.4 20 years+ 31.3 23.0 Total $378.5 $348.2 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $137.9 million and $51.9 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $0.01 million and $0.04 million , respectively, and gross losses of $0.6 million and $0.5 thousand , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $259.3 million and $219.2 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $0.1 million and $11.7 million , respectively, and gross losses of $3 million and $0.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities $520.5 $2.0 $9.3 2017 Equity Securities $818.3 $461.2 $— Debt Securities 493.8 10.9 3.6 Total $1,312.1 $472.1 $3.6 The amortized cost of available-for-sale debt securities was $527.8 million as of September 30, 2018 and $490 million as of December 31, 2017 . As of September 30, 2018 , the available-for-sale debt securities have an average coupon rate of approximately 4.07% , an average duration of approximately 6.74 years, and an average maturity of approximately 13.75 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $55 million and $66.3 million , respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $355.6 $5.8 More than 12 months 74.0 3.5 Total $429.6 $9.3 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $135.3 $1.1 More than 12 months — — 84.4 2.5 Total $— $— $219.7 $3.6 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $22.4 $23.2 1 year - 5 years 122.0 122.8 5 years - 10 years 117.9 109.3 10 years - 15 years 37.7 52.7 15 years - 20 years 41.3 50.7 20 years+ 179.2 135.1 Total $520.5 $493.8 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $773.9 million and $50.5 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $1.9 million and $2.9 million , respectively, and gross losses of $3.6 million and $0.1 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $943.3 million and $176.1 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $2.5 million and $7.9 million , respectively, and gross losses of $4.8 million and $0.4 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities $359.2 $0.9 $7.1 2017 Equity Securities $575.2 $308.6 $— Debt Securities 330.5 4.2 1.2 Total $905.7 $312.8 $1.2 The amortized cost of available-for-sale debt securities was $365.5 million as of September 30, 2018 and $327.5 million as of December 31, 2017 . As of September 30, 2018 , available-for-sale debt securities have an average coupon rate of approximately 2.95% , an average duration of approximately 6.2 years, and an average maturity of approximately 9.08 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $35.9 million and $43.8 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 investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $267.6 $5.2 More than 12 months 34.3 1.9 Total $301.9 $7.1 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $196.9 $1.0 More than 12 months — — 10.4 0.2 Total $— $— $207.3 $1.2 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $2.2 $4.1 1 year - 5 years 195.4 173.0 5 years - 10 years 78.2 78.5 10 years - 15 years 5.6 1.0 15 years - 20 years 11.0 6.9 20 years+ 66.8 67.0 Total $359.2 $330.5 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $157.8 million and $54.6 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $6.5 thousand and $0.2 million , respectively, and gross losses of $0.3 million and $0.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $357.2 million and $308.1 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $0.3 million and $0.7 million , respectively, and gross losses of $4.8 million and $1.5 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 nine months ended September 30, 2018 and 2017 . Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.
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, Vermont Yankee, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. Entergy implemented ASU No. 2016-01 “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” effective January 1, 2018. The ASU requires investments in equity securities, excluding those accounted for under the equity method or resulting in consolidation of the investee, to be measured at fair value with changes recognized in net income. Entergy implemented this ASU using a modified retrospective method, and Entergy recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by $633 million as of January 1, 2018, for the cumulative effect of the unrealized gains and losses on investments in equity securities held by the decommissioning trust funds that do not meet the criteria for regulatory accounting treatment. Beginning in 2018, unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds will be recorded in earnings as they occur rather than in other comprehensive income. In accordance with the regulatory treatment of the decommissioning trust funds of the Registrant Subsidiaries, an offsetting amount of unrealized gains/(losses) will continue to be recorded in other regulatory liabilities/assets. 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, Vermont Yankee, and Palisades do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds are held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company are recognized in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $369 million and $464 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 available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities (a) $2,448 $10 $51 2017 Equity Securities $4,662 $2,131 $1 Debt Securities 2,550 44 16 Total $7,212 $2,175 $17 (a) Debt securities presented herein do not include the $397 million of debt securities held in the wholly-owned registered investment company, which are not accounted for as available-for-sale. The unrealized gains/(losses) above are reported before deferred taxes of $472 million as of December 31, 2017 for equity securities, and ($6) million as of September 30, 2018 and $7 million as of December 31, 2017 for debt securities. The amortized cost of available-for-sale debt securities was $2,489 million as of September 30, 2018 and $2,539 million as of December 31, 2017 . As of September 30, 2018 , available-for-sale debt securities have an average coupon rate of approximately 3.36% , an average duration of approximately 5.98 years, and an average maturity of approximately 10.4 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1,691 $33 More than 12 months 357 18 Total $2,048 $51 The fair value and gross unrealized losses of available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8 $1 $1,099 $7 More than 12 months — — 265 9 Total $8 $1 $1,364 $16 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $119 $74 1 year - 5 years 934 902 5 years - 10 years 628 812 10 years - 15 years 108 147 15 years - 20 years 92 100 20 years+ 567 515 Total $2,448 $2,550 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $2,377 million and $440 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $4 million and $9 million , respectively, and gross losses of $15 million and $2 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $4,178 million and $1,903 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $6 million and $79 million , respectively, and gross losses of $37 million and $9 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of September 30, 2018 are $509 million for Indian Point 1, $644 million for Indian Point 2, $835 million for Indian Point 3, $476 million for Palisades, $1,081 million for Pilgrim, and $554 million for Vermont Yankee. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2017 are $491 million for Indian Point 1, $621 million for Indian Point 2, $798 million for Indian Point 3, $458 million for Palisades, $1,068 million for Pilgrim, and $613 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities $378.5 $0.2 $10.9 2017 Equity Securities $596.7 $354.9 $— Debt Securities 348.2 2.1 3.0 Total $944.9 $357.0 $3.0 The amortized cost of available-for-sale debt securities was $389.2 million as of September 30, 2018 and $349.1 million as of December 31, 2017 . As of September 30, 2018 , available-for-sale debt securities have an average coupon rate of approximately 2.68% , an average duration of approximately 4.6 years, and an average maturity of approximately 6.47 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $37.8 million and $46 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 investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $259.7 $6.8 More than 12 months 78.2 4.1 Total $337.9 $10.9 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $168.0 $1.2 More than 12 months — — 41.4 1.8 Total $— $— $209.4 $3.0 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $40.8 $13.0 1 year - 5 years 174.4 123.4 5 years - 10 years 115.6 180.6 10 years - 15 years 10.6 4.8 15 years - 20 years 5.8 3.4 20 years+ 31.3 23.0 Total $378.5 $348.2 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $137.9 million and $51.9 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $0.01 million and $0.04 million , respectively, and gross losses of $0.6 million and $0.5 thousand , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $259.3 million and $219.2 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $0.1 million and $11.7 million , respectively, and gross losses of $3 million and $0.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities $520.5 $2.0 $9.3 2017 Equity Securities $818.3 $461.2 $— Debt Securities 493.8 10.9 3.6 Total $1,312.1 $472.1 $3.6 The amortized cost of available-for-sale debt securities was $527.8 million as of September 30, 2018 and $490 million as of December 31, 2017 . As of September 30, 2018 , the available-for-sale debt securities have an average coupon rate of approximately 4.07% , an average duration of approximately 6.74 years, and an average maturity of approximately 13.75 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $55 million and $66.3 million , respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $355.6 $5.8 More than 12 months 74.0 3.5 Total $429.6 $9.3 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $135.3 $1.1 More than 12 months — — 84.4 2.5 Total $— $— $219.7 $3.6 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $22.4 $23.2 1 year - 5 years 122.0 122.8 5 years - 10 years 117.9 109.3 10 years - 15 years 37.7 52.7 15 years - 20 years 41.3 50.7 20 years+ 179.2 135.1 Total $520.5 $493.8 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $773.9 million and $50.5 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $1.9 million and $2.9 million , respectively, and gross losses of $3.6 million and $0.1 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $943.3 million and $176.1 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $2.5 million and $7.9 million , respectively, and gross losses of $4.8 million and $0.4 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities $359.2 $0.9 $7.1 2017 Equity Securities $575.2 $308.6 $— Debt Securities 330.5 4.2 1.2 Total $905.7 $312.8 $1.2 The amortized cost of available-for-sale debt securities was $365.5 million as of September 30, 2018 and $327.5 million as of December 31, 2017 . As of September 30, 2018 , available-for-sale debt securities have an average coupon rate of approximately 2.95% , an average duration of approximately 6.2 years, and an average maturity of approximately 9.08 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $35.9 million and $43.8 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 investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $267.6 $5.2 More than 12 months 34.3 1.9 Total $301.9 $7.1 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $196.9 $1.0 More than 12 months — — 10.4 0.2 Total $— $— $207.3 $1.2 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $2.2 $4.1 1 year - 5 years 195.4 173.0 5 years - 10 years 78.2 78.5 10 years - 15 years 5.6 1.0 15 years - 20 years 11.0 6.9 20 years+ 66.8 67.0 Total $359.2 $330.5 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $157.8 million and $54.6 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $6.5 thousand and $0.2 million , respectively, and gross losses of $0.3 million and $0.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $357.2 million and $308.1 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $0.3 million and $0.7 million , respectively, and gross losses of $4.8 million and $1.5 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 nine months ended September 30, 2018 and 2017 . Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.
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, Vermont Yankee, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. Entergy implemented ASU No. 2016-01 “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” effective January 1, 2018. The ASU requires investments in equity securities, excluding those accounted for under the equity method or resulting in consolidation of the investee, to be measured at fair value with changes recognized in net income. Entergy implemented this ASU using a modified retrospective method, and Entergy recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by $633 million as of January 1, 2018, for the cumulative effect of the unrealized gains and losses on investments in equity securities held by the decommissioning trust funds that do not meet the criteria for regulatory accounting treatment. Beginning in 2018, unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds will be recorded in earnings as they occur rather than in other comprehensive income. In accordance with the regulatory treatment of the decommissioning trust funds of the Registrant Subsidiaries, an offsetting amount of unrealized gains/(losses) will continue to be recorded in other regulatory liabilities/assets. 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, Vermont Yankee, and Palisades do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds are held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company are recognized in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $369 million and $464 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 available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities (a) $2,448 $10 $51 2017 Equity Securities $4,662 $2,131 $1 Debt Securities 2,550 44 16 Total $7,212 $2,175 $17 (a) Debt securities presented herein do not include the $397 million of debt securities held in the wholly-owned registered investment company, which are not accounted for as available-for-sale. The unrealized gains/(losses) above are reported before deferred taxes of $472 million as of December 31, 2017 for equity securities, and ($6) million as of September 30, 2018 and $7 million as of December 31, 2017 for debt securities. The amortized cost of available-for-sale debt securities was $2,489 million as of September 30, 2018 and $2,539 million as of December 31, 2017 . As of September 30, 2018 , available-for-sale debt securities have an average coupon rate of approximately 3.36% , an average duration of approximately 5.98 years, and an average maturity of approximately 10.4 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1,691 $33 More than 12 months 357 18 Total $2,048 $51 The fair value and gross unrealized losses of available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8 $1 $1,099 $7 More than 12 months — — 265 9 Total $8 $1 $1,364 $16 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $119 $74 1 year - 5 years 934 902 5 years - 10 years 628 812 10 years - 15 years 108 147 15 years - 20 years 92 100 20 years+ 567 515 Total $2,448 $2,550 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $2,377 million and $440 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $4 million and $9 million , respectively, and gross losses of $15 million and $2 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $4,178 million and $1,903 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $6 million and $79 million , respectively, and gross losses of $37 million and $9 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of September 30, 2018 are $509 million for Indian Point 1, $644 million for Indian Point 2, $835 million for Indian Point 3, $476 million for Palisades, $1,081 million for Pilgrim, and $554 million for Vermont Yankee. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2017 are $491 million for Indian Point 1, $621 million for Indian Point 2, $798 million for Indian Point 3, $458 million for Palisades, $1,068 million for Pilgrim, and $613 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities $378.5 $0.2 $10.9 2017 Equity Securities $596.7 $354.9 $— Debt Securities 348.2 2.1 3.0 Total $944.9 $357.0 $3.0 The amortized cost of available-for-sale debt securities was $389.2 million as of September 30, 2018 and $349.1 million as of December 31, 2017 . As of September 30, 2018 , available-for-sale debt securities have an average coupon rate of approximately 2.68% , an average duration of approximately 4.6 years, and an average maturity of approximately 6.47 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $37.8 million and $46 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 investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $259.7 $6.8 More than 12 months 78.2 4.1 Total $337.9 $10.9 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $168.0 $1.2 More than 12 months — — 41.4 1.8 Total $— $— $209.4 $3.0 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $40.8 $13.0 1 year - 5 years 174.4 123.4 5 years - 10 years 115.6 180.6 10 years - 15 years 10.6 4.8 15 years - 20 years 5.8 3.4 20 years+ 31.3 23.0 Total $378.5 $348.2 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $137.9 million and $51.9 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $0.01 million and $0.04 million , respectively, and gross losses of $0.6 million and $0.5 thousand , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $259.3 million and $219.2 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $0.1 million and $11.7 million , respectively, and gross losses of $3 million and $0.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities $520.5 $2.0 $9.3 2017 Equity Securities $818.3 $461.2 $— Debt Securities 493.8 10.9 3.6 Total $1,312.1 $472.1 $3.6 The amortized cost of available-for-sale debt securities was $527.8 million as of September 30, 2018 and $490 million as of December 31, 2017 . As of September 30, 2018 , the available-for-sale debt securities have an average coupon rate of approximately 4.07% , an average duration of approximately 6.74 years, and an average maturity of approximately 13.75 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $55 million and $66.3 million , respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $355.6 $5.8 More than 12 months 74.0 3.5 Total $429.6 $9.3 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $135.3 $1.1 More than 12 months — — 84.4 2.5 Total $— $— $219.7 $3.6 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $22.4 $23.2 1 year - 5 years 122.0 122.8 5 years - 10 years 117.9 109.3 10 years - 15 years 37.7 52.7 15 years - 20 years 41.3 50.7 20 years+ 179.2 135.1 Total $520.5 $493.8 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $773.9 million and $50.5 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $1.9 million and $2.9 million , respectively, and gross losses of $3.6 million and $0.1 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $943.3 million and $176.1 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $2.5 million and $7.9 million , respectively, and gross losses of $4.8 million and $0.4 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities $359.2 $0.9 $7.1 2017 Equity Securities $575.2 $308.6 $— Debt Securities 330.5 4.2 1.2 Total $905.7 $312.8 $1.2 The amortized cost of available-for-sale debt securities was $365.5 million as of September 30, 2018 and $327.5 million as of December 31, 2017 . As of September 30, 2018 , available-for-sale debt securities have an average coupon rate of approximately 2.95% , an average duration of approximately 6.2 years, and an average maturity of approximately 9.08 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $35.9 million and $43.8 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 investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $267.6 $5.2 More than 12 months 34.3 1.9 Total $301.9 $7.1 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $196.9 $1.0 More than 12 months — — 10.4 0.2 Total $— $— $207.3 $1.2 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $2.2 $4.1 1 year - 5 years 195.4 173.0 5 years - 10 years 78.2 78.5 10 years - 15 years 5.6 1.0 15 years - 20 years 11.0 6.9 20 years+ 66.8 67.0 Total $359.2 $330.5 During the three months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $157.8 million and $54.6 million , respectively. During the three months ended September 30, 2018 and 2017 , gross gains of $6.5 thousand and $0.2 million , respectively, and gross losses of $0.3 million and $0.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2018 and 2017 , proceeds from the dispositions of securities amounted to $357.2 million and $308.1 million , respectively. During the nine months ended September 30, 2018 and 2017 , gross gains of $0.3 million and $0.7 million , respectively, and gross losses of $4.8 million and $1.5 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 nine months ended September 30, 2018 and 2017 . Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2018
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. 2012-2013 IRS Audit The IRS completed its examination of the 2012 and 2013 tax years and issued its 2012-2013 Revenue Agent Report (RAR) in June 2018. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of these adjustments in June 2018. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits of $52 million related to the Hurricane Katrina and Hurricane Rita contingent sharing obligation associated with the Louisiana Act 55 financing. The conclusion and settlement of the IRS audit described above caused a decrease in Entergy Louisiana’s balance of unrecognized tax benefits, which changed from $926 million as of December 31, 2017 to $855 million as of September 30, 2018, net of carryovers for losses and credits. The reduction of unrecognized tax benefits was primarily recorded in the second quarter 2018 with no significant additional changes to Entergy Louisiana’s unrecognized tax benefit balance recognized during the third quarter 2018. Tax Cuts and Jobs Act As discussed in the Form 10-K, the Tax Cuts and Jobs Act limits the deduction for net business interest expense in certain circumstances. The limitation does not apply to interest expense allocable to the Utility. In Notice 2018-28 released on April 2, 2018, the IRS announced that it intends to issue proposed regulations that will provide guidance to assist taxpayers in complying with the new interest provisions under the Tax Cuts and Jobs Act. The notice provides general and limited information of the IRS’s interpretation regarding methodologies that could be used for the allocation of the interest expense limitation. As a result of the new provision contained in the Tax Cuts and Jobs Act, Entergy recorded limitations in 2018 which did not have a material effect on financial position, results of operations, or cash flows. For a discussion of proceedings commenced or other responses by Entergy’s regulators to the Tax Cuts and Jobs Act, see Note 2 to the financial statements herein and in the Form 10-K. During the second and third quarters of 2018, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans and System Energy 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 each Registrant Subsidiary’s respective regulatory commission. 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. In the third quarter 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy Arkansas, $153 million ; Entergy Louisiana, $55 million ; Entergy Mississippi, $32 million ; Entergy New Orleans, $9 million ; and System Energy, $34 million . In the nine months ended September 30, 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy Arkansas, $260 million ; Entergy Louisiana, $86 million ; Entergy Mississippi, $161 million ; Entergy New Orleans, $9 million ; and System Energy, $46 million . As discussed in Note 2 to the financial statements herein, the unopposed settlement of Entergy Texas’s 2018 rate case, if approved by the PUCT, establishes the amounts of protected and unprotected excess accumulated deferred income taxes that Entergy Texas will return to customers. As of September 30, 2018, Entergy Texas’s regulatory liability for protected excess accumulated deferred income taxes was $269 million and its regulatory liability for unprotected excess accumulated deferred income taxes was $201 million . Other Tax Matters In the third quarter 2018, Entergy completed a restructuring of the investment holdings in one of the Entergy Wholesale Commodities nuclear plant decommissioning trusts that resulted in an adjustment to tax basis for the trust. The accounting standards provide that a taxable temporary difference does not exist if the tax law provides a means by which an amount can be recovered without incurrence of tax. The restructuring allows Entergy to recover assets from the trust without incurring tax. As such, the tax basis recognized resulted in the reversal of a deferred tax liability and reduction of income tax expense of approximately $107 million . A state income tax audit involving Entergy Wholesale Commodities was concluded during the third quarter 2018. Upon conclusion of the audit, subsidiaries within Entergy Wholesale Commodities reversed a portion of the provision for uncertain tax positions totaling approximately $23 million , net of tax and interest paid.
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. 2012-2013 IRS Audit The IRS completed its examination of the 2012 and 2013 tax years and issued its 2012-2013 Revenue Agent Report (RAR) in June 2018. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of these adjustments in June 2018. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits of $52 million related to the Hurricane Katrina and Hurricane Rita contingent sharing obligation associated with the Louisiana Act 55 financing. The conclusion and settlement of the IRS audit described above caused a decrease in Entergy Louisiana’s balance of unrecognized tax benefits, which changed from $926 million as of December 31, 2017 to $855 million as of September 30, 2018, net of carryovers for losses and credits. The reduction of unrecognized tax benefits was primarily recorded in the second quarter 2018 with no significant additional changes to Entergy Louisiana’s unrecognized tax benefit balance recognized during the third quarter 2018. Tax Cuts and Jobs Act As discussed in the Form 10-K, the Tax Cuts and Jobs Act limits the deduction for net business interest expense in certain circumstances. The limitation does not apply to interest expense allocable to the Utility. In Notice 2018-28 released on April 2, 2018, the IRS announced that it intends to issue proposed regulations that will provide guidance to assist taxpayers in complying with the new interest provisions under the Tax Cuts and Jobs Act. The notice provides general and limited information of the IRS’s interpretation regarding methodologies that could be used for the allocation of the interest expense limitation. As a result of the new provision contained in the Tax Cuts and Jobs Act, Entergy recorded limitations in 2018 which did not have a material effect on financial position, results of operations, or cash flows. For a discussion of proceedings commenced or other responses by Entergy’s regulators to the Tax Cuts and Jobs Act, see Note 2 to the financial statements herein and in the Form 10-K. During the second and third quarters of 2018, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans and System Energy 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 each Registrant Subsidiary’s respective regulatory commission. 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. In the third quarter 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy Arkansas, $153 million ; Entergy Louisiana, $55 million ; Entergy Mississippi, $32 million ; Entergy New Orleans, $9 million ; and System Energy, $34 million . In the nine months ended September 30, 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy Arkansas, $260 million ; Entergy Louisiana, $86 million ; Entergy Mississippi, $161 million ; Entergy New Orleans, $9 million ; and System Energy, $46 million . As discussed in Note 2 to the financial statements herein, the unopposed settlement of Entergy Texas’s 2018 rate case, if approved by the PUCT, establishes the amounts of protected and unprotected excess accumulated deferred income taxes that Entergy Texas will return to customers. As of September 30, 2018, Entergy Texas’s regulatory liability for protected excess accumulated deferred income taxes was $269 million and its regulatory liability for unprotected excess accumulated deferred income taxes was $201 million . Other Tax Matters In the third quarter 2018, Entergy completed a restructuring of the investment holdings in one of the Entergy Wholesale Commodities nuclear plant decommissioning trusts that resulted in an adjustment to tax basis for the trust. The accounting standards provide that a taxable temporary difference does not exist if the tax law provides a means by which an amount can be recovered without incurrence of tax. The restructuring allows Entergy to recover assets from the trust without incurring tax. As such, the tax basis recognized resulted in the reversal of a deferred tax liability and reduction of income tax expense of approximately $107 million . A state income tax audit involving Entergy Wholesale Commodities was concluded during the third quarter 2018. Upon conclusion of the audit, subsidiaries within Entergy Wholesale Commodities reversed a portion of the provision for uncertain tax positions totaling approximately $23 million , net of tax and interest paid.
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. 2012-2013 IRS Audit The IRS completed its examination of the 2012 and 2013 tax years and issued its 2012-2013 Revenue Agent Report (RAR) in June 2018. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of these adjustments in June 2018. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits of $52 million related to the Hurricane Katrina and Hurricane Rita contingent sharing obligation associated with the Louisiana Act 55 financing. The conclusion and settlement of the IRS audit described above caused a decrease in Entergy Louisiana’s balance of unrecognized tax benefits, which changed from $926 million as of December 31, 2017 to $855 million as of September 30, 2018, net of carryovers for losses and credits. The reduction of unrecognized tax benefits was primarily recorded in the second quarter 2018 with no significant additional changes to Entergy Louisiana’s unrecognized tax benefit balance recognized during the third quarter 2018. Tax Cuts and Jobs Act As discussed in the Form 10-K, the Tax Cuts and Jobs Act limits the deduction for net business interest expense in certain circumstances. The limitation does not apply to interest expense allocable to the Utility. In Notice 2018-28 released on April 2, 2018, the IRS announced that it intends to issue proposed regulations that will provide guidance to assist taxpayers in complying with the new interest provisions under the Tax Cuts and Jobs Act. The notice provides general and limited information of the IRS’s interpretation regarding methodologies that could be used for the allocation of the interest expense limitation. As a result of the new provision contained in the Tax Cuts and Jobs Act, Entergy recorded limitations in 2018 which did not have a material effect on financial position, results of operations, or cash flows. For a discussion of proceedings commenced or other responses by Entergy’s regulators to the Tax Cuts and Jobs Act, see Note 2 to the financial statements herein and in the Form 10-K. During the second and third quarters of 2018, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans and System Energy 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 each Registrant Subsidiary’s respective regulatory commission. 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. In the third quarter 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy Arkansas, $153 million ; Entergy Louisiana, $55 million ; Entergy Mississippi, $32 million ; Entergy New Orleans, $9 million ; and System Energy, $34 million . In the nine months ended September 30, 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy Arkansas, $260 million ; Entergy Louisiana, $86 million ; Entergy Mississippi, $161 million ; Entergy New Orleans, $9 million ; and System Energy, $46 million . As discussed in Note 2 to the financial statements herein, the unopposed settlement of Entergy Texas’s 2018 rate case, if approved by the PUCT, establishes the amounts of protected and unprotected excess accumulated deferred income taxes that Entergy Texas will return to customers. As of September 30, 2018, Entergy Texas’s regulatory liability for protected excess accumulated deferred income taxes was $269 million and its regulatory liability for unprotected excess accumulated deferred income taxes was $201 million . Other Tax Matters In the third quarter 2018, Entergy completed a restructuring of the investment holdings in one of the Entergy Wholesale Commodities nuclear plant decommissioning trusts that resulted in an adjustment to tax basis for the trust. The accounting standards provide that a taxable temporary difference does not exist if the tax law provides a means by which an amount can be recovered without incurrence of tax. The restructuring allows Entergy to recover assets from the trust without incurring tax. As such, the tax basis recognized resulted in the reversal of a deferred tax liability and reduction of income tax expense of approximately $107 million . A state income tax audit involving Entergy Wholesale Commodities was concluded during the third quarter 2018. Upon conclusion of the audit, subsidiaries within Entergy Wholesale Commodities reversed a portion of the provision for uncertain tax positions totaling approximately $23 million , net of tax and interest paid.
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. 2012-2013 IRS Audit The IRS completed its examination of the 2012 and 2013 tax years and issued its 2012-2013 Revenue Agent Report (RAR) in June 2018. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of these adjustments in June 2018. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits of $52 million related to the Hurricane Katrina and Hurricane Rita contingent sharing obligation associated with the Louisiana Act 55 financing. The conclusion and settlement of the IRS audit described above caused a decrease in Entergy Louisiana’s balance of unrecognized tax benefits, which changed from $926 million as of December 31, 2017 to $855 million as of September 30, 2018, net of carryovers for losses and credits. The reduction of unrecognized tax benefits was primarily recorded in the second quarter 2018 with no significant additional changes to Entergy Louisiana’s unrecognized tax benefit balance recognized during the third quarter 2018. Tax Cuts and Jobs Act As discussed in the Form 10-K, the Tax Cuts and Jobs Act limits the deduction for net business interest expense in certain circumstances. The limitation does not apply to interest expense allocable to the Utility. In Notice 2018-28 released on April 2, 2018, the IRS announced that it intends to issue proposed regulations that will provide guidance to assist taxpayers in complying with the new interest provisions under the Tax Cuts and Jobs Act. The notice provides general and limited information of the IRS’s interpretation regarding methodologies that could be used for the allocation of the interest expense limitation. As a result of the new provision contained in the Tax Cuts and Jobs Act, Entergy recorded limitations in 2018 which did not have a material effect on financial position, results of operations, or cash flows. For a discussion of proceedings commenced or other responses by Entergy’s regulators to the Tax Cuts and Jobs Act, see Note 2 to the financial statements herein and in the Form 10-K. During the second and third quarters of 2018, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans and System Energy 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 each Registrant Subsidiary’s respective regulatory commission. 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. In the third quarter 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy Arkansas, $153 million ; Entergy Louisiana, $55 million ; Entergy Mississippi, $32 million ; Entergy New Orleans, $9 million ; and System Energy, $34 million . In the nine months ended September 30, 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy Arkansas, $260 million ; Entergy Louisiana, $86 million ; Entergy Mississippi, $161 million ; Entergy New Orleans, $9 million ; and System Energy, $46 million . As discussed in Note 2 to the financial statements herein, the unopposed settlement of Entergy Texas’s 2018 rate case, if approved by the PUCT, establishes the amounts of protected and unprotected excess accumulated deferred income taxes that Entergy Texas will return to customers. As of September 30, 2018, Entergy Texas’s regulatory liability for protected excess accumulated deferred income taxes was $269 million and its regulatory liability for unprotected excess accumulated deferred income taxes was $201 million . Other Tax Matters In the third quarter 2018, Entergy completed a restructuring of the investment holdings in one of the Entergy Wholesale Commodities nuclear plant decommissioning trusts that resulted in an adjustment to tax basis for the trust. The accounting standards provide that a taxable temporary difference does not exist if the tax law provides a means by which an amount can be recovered without incurrence of tax. The restructuring allows Entergy to recover assets from the trust without incurring tax. As such, the tax basis recognized resulted in the reversal of a deferred tax liability and reduction of income tax expense of approximately $107 million . A state income tax audit involving Entergy Wholesale Commodities was concluded during the third quarter 2018. Upon conclusion of the audit, subsidiaries within Entergy Wholesale Commodities reversed a portion of the provision for uncertain tax positions totaling approximately $23 million , net of tax and interest paid.
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. 2012-2013 IRS Audit The IRS completed its examination of the 2012 and 2013 tax years and issued its 2012-2013 Revenue Agent Report (RAR) in June 2018. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of these adjustments in June 2018. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits of $52 million related to the Hurricane Katrina and Hurricane Rita contingent sharing obligation associated with the Louisiana Act 55 financing. The conclusion and settlement of the IRS audit described above caused a decrease in Entergy Louisiana’s balance of unrecognized tax benefits, which changed from $926 million as of December 31, 2017 to $855 million as of September 30, 2018, net of carryovers for losses and credits. The reduction of unrecognized tax benefits was primarily recorded in the second quarter 2018 with no significant additional changes to Entergy Louisiana’s unrecognized tax benefit balance recognized during the third quarter 2018. Tax Cuts and Jobs Act As discussed in the Form 10-K, the Tax Cuts and Jobs Act limits the deduction for net business interest expense in certain circumstances. The limitation does not apply to interest expense allocable to the Utility. In Notice 2018-28 released on April 2, 2018, the IRS announced that it intends to issue proposed regulations that will provide guidance to assist taxpayers in complying with the new interest provisions under the Tax Cuts and Jobs Act. The notice provides general and limited information of the IRS’s interpretation regarding methodologies that could be used for the allocation of the interest expense limitation. As a result of the new provision contained in the Tax Cuts and Jobs Act, Entergy recorded limitations in 2018 which did not have a material effect on financial position, results of operations, or cash flows. For a discussion of proceedings commenced or other responses by Entergy’s regulators to the Tax Cuts and Jobs Act, see Note 2 to the financial statements herein and in the Form 10-K. During the second and third quarters of 2018, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans and System Energy 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 each Registrant Subsidiary’s respective regulatory commission. 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. In the third quarter 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy Arkansas, $153 million ; Entergy Louisiana, $55 million ; Entergy Mississippi, $32 million ; Entergy New Orleans, $9 million ; and System Energy, $34 million . In the nine months ended September 30, 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy Arkansas, $260 million ; Entergy Louisiana, $86 million ; Entergy Mississippi, $161 million ; Entergy New Orleans, $9 million ; and System Energy, $46 million . As discussed in Note 2 to the financial statements herein, the unopposed settlement of Entergy Texas’s 2018 rate case, if approved by the PUCT, establishes the amounts of protected and unprotected excess accumulated deferred income taxes that Entergy Texas will return to customers. As of September 30, 2018, Entergy Texas’s regulatory liability for protected excess accumulated deferred income taxes was $269 million and its regulatory liability for unprotected excess accumulated deferred income taxes was $201 million . Other Tax Matters In the third quarter 2018, Entergy completed a restructuring of the investment holdings in one of the Entergy Wholesale Commodities nuclear plant decommissioning trusts that resulted in an adjustment to tax basis for the trust. The accounting standards provide that a taxable temporary difference does not exist if the tax law provides a means by which an amount can be recovered without incurrence of tax. The restructuring allows Entergy to recover assets from the trust without incurring tax. As such, the tax basis recognized resulted in the reversal of a deferred tax liability and reduction of income tax expense of approximately $107 million . A state income tax audit involving Entergy Wholesale Commodities was concluded during the third quarter 2018. Upon conclusion of the audit, subsidiaries within Entergy Wholesale Commodities reversed a portion of the provision for uncertain tax positions totaling approximately $23 million , net of tax and interest paid.
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. 2012-2013 IRS Audit The IRS completed its examination of the 2012 and 2013 tax years and issued its 2012-2013 Revenue Agent Report (RAR) in June 2018. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of these adjustments in June 2018. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits of $52 million related to the Hurricane Katrina and Hurricane Rita contingent sharing obligation associated with the Louisiana Act 55 financing. The conclusion and settlement of the IRS audit described above caused a decrease in Entergy Louisiana’s balance of unrecognized tax benefits, which changed from $926 million as of December 31, 2017 to $855 million as of September 30, 2018, net of carryovers for losses and credits. The reduction of unrecognized tax benefits was primarily recorded in the second quarter 2018 with no significant additional changes to Entergy Louisiana’s unrecognized tax benefit balance recognized during the third quarter 2018. Tax Cuts and Jobs Act As discussed in the Form 10-K, the Tax Cuts and Jobs Act limits the deduction for net business interest expense in certain circumstances. The limitation does not apply to interest expense allocable to the Utility. In Notice 2018-28 released on April 2, 2018, the IRS announced that it intends to issue proposed regulations that will provide guidance to assist taxpayers in complying with the new interest provisions under the Tax Cuts and Jobs Act. The notice provides general and limited information of the IRS’s interpretation regarding methodologies that could be used for the allocation of the interest expense limitation. As a result of the new provision contained in the Tax Cuts and Jobs Act, Entergy recorded limitations in 2018 which did not have a material effect on financial position, results of operations, or cash flows. For a discussion of proceedings commenced or other responses by Entergy’s regulators to the Tax Cuts and Jobs Act, see Note 2 to the financial statements herein and in the Form 10-K. During the second and third quarters of 2018, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans and System Energy 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 each Registrant Subsidiary’s respective regulatory commission. 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. In the third quarter 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy Arkansas, $153 million ; Entergy Louisiana, $55 million ; Entergy Mississippi, $32 million ; Entergy New Orleans, $9 million ; and System Energy, $34 million . In the nine months ended September 30, 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy Arkansas, $260 million ; Entergy Louisiana, $86 million ; Entergy Mississippi, $161 million ; Entergy New Orleans, $9 million ; and System Energy, $46 million . As discussed in Note 2 to the financial statements herein, the unopposed settlement of Entergy Texas’s 2018 rate case, if approved by the PUCT, establishes the amounts of protected and unprotected excess accumulated deferred income taxes that Entergy Texas will return to customers. As of September 30, 2018, Entergy Texas’s regulatory liability for protected excess accumulated deferred income taxes was $269 million and its regulatory liability for unprotected excess accumulated deferred income taxes was $201 million . Other Tax Matters In the third quarter 2018, Entergy completed a restructuring of the investment holdings in one of the Entergy Wholesale Commodities nuclear plant decommissioning trusts that resulted in an adjustment to tax basis for the trust. The accounting standards provide that a taxable temporary difference does not exist if the tax law provides a means by which an amount can be recovered without incurrence of tax. The restructuring allows Entergy to recover assets from the trust without incurring tax. As such, the tax basis recognized resulted in the reversal of a deferred tax liability and reduction of income tax expense of approximately $107 million . A state income tax audit involving Entergy Wholesale Commodities was concluded during the third quarter 2018. Upon conclusion of the audit, subsidiaries within Entergy Wholesale Commodities reversed a portion of the provision for uncertain tax positions totaling approximately $23 million , net of tax and interest paid.
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. 2012-2013 IRS Audit The IRS completed its examination of the 2012 and 2013 tax years and issued its 2012-2013 Revenue Agent Report (RAR) in June 2018. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of these adjustments in June 2018. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits of $52 million related to the Hurricane Katrina and Hurricane Rita contingent sharing obligation associated with the Louisiana Act 55 financing. The conclusion and settlement of the IRS audit described above caused a decrease in Entergy Louisiana’s balance of unrecognized tax benefits, which changed from $926 million as of December 31, 2017 to $855 million as of September 30, 2018, net of carryovers for losses and credits. The reduction of unrecognized tax benefits was primarily recorded in the second quarter 2018 with no significant additional changes to Entergy Louisiana’s unrecognized tax benefit balance recognized during the third quarter 2018. Tax Cuts and Jobs Act As discussed in the Form 10-K, the Tax Cuts and Jobs Act limits the deduction for net business interest expense in certain circumstances. The limitation does not apply to interest expense allocable to the Utility. In Notice 2018-28 released on April 2, 2018, the IRS announced that it intends to issue proposed regulations that will provide guidance to assist taxpayers in complying with the new interest provisions under the Tax Cuts and Jobs Act. The notice provides general and limited information of the IRS’s interpretation regarding methodologies that could be used for the allocation of the interest expense limitation. As a result of the new provision contained in the Tax Cuts and Jobs Act, Entergy recorded limitations in 2018 which did not have a material effect on financial position, results of operations, or cash flows. For a discussion of proceedings commenced or other responses by Entergy’s regulators to the Tax Cuts and Jobs Act, see Note 2 to the financial statements herein and in the Form 10-K. During the second and third quarters of 2018, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans and System Energy 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 each Registrant Subsidiary’s respective regulatory commission. 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. In the third quarter 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy Arkansas, $153 million ; Entergy Louisiana, $55 million ; Entergy Mississippi, $32 million ; Entergy New Orleans, $9 million ; and System Energy, $34 million . In the nine months ended September 30, 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy Arkansas, $260 million ; Entergy Louisiana, $86 million ; Entergy Mississippi, $161 million ; Entergy New Orleans, $9 million ; and System Energy, $46 million . As discussed in Note 2 to the financial statements herein, the unopposed settlement of Entergy Texas’s 2018 rate case, if approved by the PUCT, establishes the amounts of protected and unprotected excess accumulated deferred income taxes that Entergy Texas will return to customers. As of September 30, 2018, Entergy Texas’s regulatory liability for protected excess accumulated deferred income taxes was $269 million and its regulatory liability for unprotected excess accumulated deferred income taxes was $201 million . Other Tax Matters In the third quarter 2018, Entergy completed a restructuring of the investment holdings in one of the Entergy Wholesale Commodities nuclear plant decommissioning trusts that resulted in an adjustment to tax basis for the trust. The accounting standards provide that a taxable temporary difference does not exist if the tax law provides a means by which an amount can be recovered without incurrence of tax. The restructuring allows Entergy to recover assets from the trust without incurring tax. As such, the tax basis recognized resulted in the reversal of a deferred tax liability and reduction of income tax expense of approximately $107 million . A state income tax audit involving Entergy Wholesale Commodities was concluded during the third quarter 2018. Upon conclusion of the audit, subsidiaries within Entergy Wholesale Commodities reversed a portion of the provision for uncertain tax positions totaling approximately $23 million , net of tax and interest paid.

Property, Plant, And Equipment

Property, Plant, And Equipment	9 Months Ended
	Sep. 30, 2018
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at September 30, 2018 are $255 million for Entergy, $27.8 million for Entergy Arkansas, $80.1 million for Entergy Louisiana, $8.9 million for Entergy Mississippi, $18.7 million for Entergy New Orleans, $13.9 million for Entergy Texas, and $38.1 million for System Energy. Construction expenditures included in accounts payable at December 31, 2017 are $368 million for Entergy, $58.8 million for Entergy Arkansas, $160.4 million for Entergy Louisiana, $17.1 million for Entergy Mississippi, $2.5 million for Entergy New Orleans, $32.8 million for Entergy Texas, and $33.9 million for System Energy.
Entergy Arkansas [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at September 30, 2018 are $255 million for Entergy, $27.8 million for Entergy Arkansas, $80.1 million for Entergy Louisiana, $8.9 million for Entergy Mississippi, $18.7 million for Entergy New Orleans, $13.9 million for Entergy Texas, and $38.1 million for System Energy. Construction expenditures included in accounts payable at December 31, 2017 are $368 million for Entergy, $58.8 million for Entergy Arkansas, $160.4 million for Entergy Louisiana, $17.1 million for Entergy Mississippi, $2.5 million for Entergy New Orleans, $32.8 million for Entergy Texas, and $33.9 million for System Energy.
Entergy Louisiana [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at September 30, 2018 are $255 million for Entergy, $27.8 million for Entergy Arkansas, $80.1 million for Entergy Louisiana, $8.9 million for Entergy Mississippi, $18.7 million for Entergy New Orleans, $13.9 million for Entergy Texas, and $38.1 million for System Energy. Construction expenditures included in accounts payable at December 31, 2017 are $368 million for Entergy, $58.8 million for Entergy Arkansas, $160.4 million for Entergy Louisiana, $17.1 million for Entergy Mississippi, $2.5 million for Entergy New Orleans, $32.8 million for Entergy Texas, and $33.9 million for System Energy.
Entergy Mississippi [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at September 30, 2018 are $255 million for Entergy, $27.8 million for Entergy Arkansas, $80.1 million for Entergy Louisiana, $8.9 million for Entergy Mississippi, $18.7 million for Entergy New Orleans, $13.9 million for Entergy Texas, and $38.1 million for System Energy. Construction expenditures included in accounts payable at December 31, 2017 are $368 million for Entergy, $58.8 million for Entergy Arkansas, $160.4 million for Entergy Louisiana, $17.1 million for Entergy Mississippi, $2.5 million for Entergy New Orleans, $32.8 million for Entergy Texas, and $33.9 million for System Energy.
Entergy New Orleans [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at September 30, 2018 are $255 million for Entergy, $27.8 million for Entergy Arkansas, $80.1 million for Entergy Louisiana, $8.9 million for Entergy Mississippi, $18.7 million for Entergy New Orleans, $13.9 million for Entergy Texas, and $38.1 million for System Energy. Construction expenditures included in accounts payable at December 31, 2017 are $368 million for Entergy, $58.8 million for Entergy Arkansas, $160.4 million for Entergy Louisiana, $17.1 million for Entergy Mississippi, $2.5 million for Entergy New Orleans, $32.8 million for Entergy Texas, and $33.9 million for System Energy.
Entergy Texas [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at September 30, 2018 are $255 million for Entergy, $27.8 million for Entergy Arkansas, $80.1 million for Entergy Louisiana, $8.9 million for Entergy Mississippi, $18.7 million for Entergy New Orleans, $13.9 million for Entergy Texas, and $38.1 million for System Energy. Construction expenditures included in accounts payable at December 31, 2017 are $368 million for Entergy, $58.8 million for Entergy Arkansas, $160.4 million for Entergy Louisiana, $17.1 million for Entergy Mississippi, $2.5 million for Entergy New Orleans, $32.8 million for Entergy Texas, and $33.9 million for System Energy.
System Energy [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at September 30, 2018 are $255 million for Entergy, $27.8 million for Entergy Arkansas, $80.1 million for Entergy Louisiana, $8.9 million for Entergy Mississippi, $18.7 million for Entergy New Orleans, $13.9 million for Entergy Texas, and $38.1 million for System Energy. Construction expenditures included in accounts payable at December 31, 2017 are $368 million for Entergy, $58.8 million for Entergy Arkansas, $160.4 million for Entergy Louisiana, $17.1 million for Entergy Mississippi, $2.5 million for Entergy New Orleans, $32.8 million for Entergy Texas, and $33.9 million for System Energy.

Variable Interest Entities

Variable Interest Entities	9 Months Ended
	Sep. 30, 2018
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 on its lease, including interest, of $8.6 million in the three months ended September 30, 2018 and in the three months ended September 30, 2017 . System Energy made payments on its lease, including interest, of $17.2 million in the nine months ended September 30, 2018 and in the nine months ended September 30, 2017 .
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 on its lease, including interest, of $8.6 million in the three months ended September 30, 2018 and in the three months ended September 30, 2017 . System Energy made payments on its lease, including interest, of $17.2 million in the nine months ended September 30, 2018 and in the nine months ended September 30, 2017 .
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 on its lease, including interest, of $8.6 million in the three months ended September 30, 2018 and in the three months ended September 30, 2017 . System Energy made payments on its lease, including interest, of $17.2 million in the nine months ended September 30, 2018 and in the nine months ended September 30, 2017 .
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 on its lease, including interest, of $8.6 million in the three months ended September 30, 2018 and in the three months ended September 30, 2017 . System Energy made payments on its lease, including interest, of $17.2 million in the nine months ended September 30, 2018 and in the nine months ended September 30, 2017 .
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 on its lease, including interest, of $8.6 million in the three months ended September 30, 2018 and in the three months ended September 30, 2017 . System Energy made payments on its lease, including interest, of $17.2 million in the nine months ended September 30, 2018 and in the nine months ended September 30, 2017 .
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 on its lease, including interest, of $8.6 million in the three months ended September 30, 2018 and in the three months ended September 30, 2017 . System Energy made payments on its lease, including interest, of $17.2 million in the nine months ended September 30, 2018 and in the nine months ended September 30, 2017 .
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 on its lease, including interest, of $8.6 million in the three months ended September 30, 2018 and in the three months ended September 30, 2017 . System Energy made payments on its lease, including interest, of $17.2 million in the nine months ended September 30, 2018 and in the nine months ended September 30, 2017 .

Revenue Recognition

Revenue Recognition	9 Months Ended
	Sep. 30, 2018
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenue Recognition Entergy implemented ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” effective January 1, 2018. Topic 606 requires entities to “recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.” The ASU details a five-step model that should be followed to achieve the core principle. This accounting was applied to all contracts using the modified retrospective method, which requires an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date. Because the standard did not result in any material change in how Entergy recognizes revenue, however, no adjustment to retained earnings was required. Similarly, there was no effect on revenues recognized under Topic 606 for the three or nine months ended September 30, 2018. Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the three and nine months ended September 30, 2018 were as follows: 2018 Three Months Ended Nine Months Ended (In Thousands) Utility: Residential $1,138,744 $2,799,539 Commercial 693,760 1,871,380 Industrial 682,823 1,904,828 Governmental 60,647 173,949 Total billed retail 2,575,974 6,749,696 Sales for resale (a) 76,247 214,984 Other electric revenues (b) 42,847 289,668 Non-customer revenues (c) 2,819 22,026 Total electric revenues 2,697,887 7,276,374 Natural gas 26,352 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 407,763 1,148,460 Non-customer revenues (c) (27,683 ) (40,854 ) Total competitive businesses 380,080 1,107,606 Total operating revenues $3,104,319 $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Energy is provided on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. This may result in variability of reported revenues from one period to the next as prior estimates are reversed and new estimates recorded. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as non-customer revenue in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and the City of New Orleans, including Algiers, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities revenues are from Entergy’s nuclear power plants located in the northern United States. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Most of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in 2022. The PPA prices are for a set price per MWh and escalate each year, up to $61.50 /MWh in 2022. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. Additionally, as the PPA pricing was considered below-market at the time of acquisition, a liability was recorded for the fair value of the below-market PPA, and is being amortized to revenue over the life of the agreement. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues.
Entergy Arkansas [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenue Recognition Entergy implemented ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” effective January 1, 2018. Topic 606 requires entities to “recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.” The ASU details a five-step model that should be followed to achieve the core principle. This accounting was applied to all contracts using the modified retrospective method, which requires an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date. Because the standard did not result in any material change in how Entergy recognizes revenue, however, no adjustment to retained earnings was required. Similarly, there was no effect on revenues recognized under Topic 606 for the three or nine months ended September 30, 2018. Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the three and nine months ended September 30, 2018 were as follows: 2018 Three Months Ended Nine Months Ended (In Thousands) Utility: Residential $1,138,744 $2,799,539 Commercial 693,760 1,871,380 Industrial 682,823 1,904,828 Governmental 60,647 173,949 Total billed retail 2,575,974 6,749,696 Sales for resale (a) 76,247 214,984 Other electric revenues (b) 42,847 289,668 Non-customer revenues (c) 2,819 22,026 Total electric revenues 2,697,887 7,276,374 Natural gas 26,352 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 407,763 1,148,460 Non-customer revenues (c) (27,683 ) (40,854 ) Total competitive businesses 380,080 1,107,606 Total operating revenues $3,104,319 $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Energy is provided on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. This may result in variability of reported revenues from one period to the next as prior estimates are reversed and new estimates recorded. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as non-customer revenue in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and the City of New Orleans, including Algiers, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities revenues are from Entergy’s nuclear power plants located in the northern United States. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Most of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in 2022. The PPA prices are for a set price per MWh and escalate each year, up to $61.50 /MWh in 2022. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. Additionally, as the PPA pricing was considered below-market at the time of acquisition, a liability was recorded for the fair value of the below-market PPA, and is being amortized to revenue over the life of the agreement. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues.
Entergy Louisiana [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenue Recognition Entergy implemented ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” effective January 1, 2018. Topic 606 requires entities to “recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.” The ASU details a five-step model that should be followed to achieve the core principle. This accounting was applied to all contracts using the modified retrospective method, which requires an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date. Because the standard did not result in any material change in how Entergy recognizes revenue, however, no adjustment to retained earnings was required. Similarly, there was no effect on revenues recognized under Topic 606 for the three or nine months ended September 30, 2018. Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the three and nine months ended September 30, 2018 were as follows: 2018 Three Months Ended Nine Months Ended (In Thousands) Utility: Residential $1,138,744 $2,799,539 Commercial 693,760 1,871,380 Industrial 682,823 1,904,828 Governmental 60,647 173,949 Total billed retail 2,575,974 6,749,696 Sales for resale (a) 76,247 214,984 Other electric revenues (b) 42,847 289,668 Non-customer revenues (c) 2,819 22,026 Total electric revenues 2,697,887 7,276,374 Natural gas 26,352 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 407,763 1,148,460 Non-customer revenues (c) (27,683 ) (40,854 ) Total competitive businesses 380,080 1,107,606 Total operating revenues $3,104,319 $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Energy is provided on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. This may result in variability of reported revenues from one period to the next as prior estimates are reversed and new estimates recorded. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as non-customer revenue in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and the City of New Orleans, including Algiers, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities revenues are from Entergy’s nuclear power plants located in the northern United States. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Most of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in 2022. The PPA prices are for a set price per MWh and escalate each year, up to $61.50 /MWh in 2022. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. Additionally, as the PPA pricing was considered below-market at the time of acquisition, a liability was recorded for the fair value of the below-market PPA, and is being amortized to revenue over the life of the agreement. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues.
Entergy Mississippi [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenue Recognition Entergy implemented ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” effective January 1, 2018. Topic 606 requires entities to “recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.” The ASU details a five-step model that should be followed to achieve the core principle. This accounting was applied to all contracts using the modified retrospective method, which requires an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date. Because the standard did not result in any material change in how Entergy recognizes revenue, however, no adjustment to retained earnings was required. Similarly, there was no effect on revenues recognized under Topic 606 for the three or nine months ended September 30, 2018. Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the three and nine months ended September 30, 2018 were as follows: 2018 Three Months Ended Nine Months Ended (In Thousands) Utility: Residential $1,138,744 $2,799,539 Commercial 693,760 1,871,380 Industrial 682,823 1,904,828 Governmental 60,647 173,949 Total billed retail 2,575,974 6,749,696 Sales for resale (a) 76,247 214,984 Other electric revenues (b) 42,847 289,668 Non-customer revenues (c) 2,819 22,026 Total electric revenues 2,697,887 7,276,374 Natural gas 26,352 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 407,763 1,148,460 Non-customer revenues (c) (27,683 ) (40,854 ) Total competitive businesses 380,080 1,107,606 Total operating revenues $3,104,319 $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Energy is provided on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. This may result in variability of reported revenues from one period to the next as prior estimates are reversed and new estimates recorded. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as non-customer revenue in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and the City of New Orleans, including Algiers, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities revenues are from Entergy’s nuclear power plants located in the northern United States. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Most of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in 2022. The PPA prices are for a set price per MWh and escalate each year, up to $61.50 /MWh in 2022. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. Additionally, as the PPA pricing was considered below-market at the time of acquisition, a liability was recorded for the fair value of the below-market PPA, and is being amortized to revenue over the life of the agreement. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues.
Entergy New Orleans [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenue Recognition Entergy implemented ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” effective January 1, 2018. Topic 606 requires entities to “recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.” The ASU details a five-step model that should be followed to achieve the core principle. This accounting was applied to all contracts using the modified retrospective method, which requires an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date. Because the standard did not result in any material change in how Entergy recognizes revenue, however, no adjustment to retained earnings was required. Similarly, there was no effect on revenues recognized under Topic 606 for the three or nine months ended September 30, 2018. Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the three and nine months ended September 30, 2018 were as follows: 2018 Three Months Ended Nine Months Ended (In Thousands) Utility: Residential $1,138,744 $2,799,539 Commercial 693,760 1,871,380 Industrial 682,823 1,904,828 Governmental 60,647 173,949 Total billed retail 2,575,974 6,749,696 Sales for resale (a) 76,247 214,984 Other electric revenues (b) 42,847 289,668 Non-customer revenues (c) 2,819 22,026 Total electric revenues 2,697,887 7,276,374 Natural gas 26,352 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 407,763 1,148,460 Non-customer revenues (c) (27,683 ) (40,854 ) Total competitive businesses 380,080 1,107,606 Total operating revenues $3,104,319 $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Energy is provided on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. This may result in variability of reported revenues from one period to the next as prior estimates are reversed and new estimates recorded. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as non-customer revenue in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and the City of New Orleans, including Algiers, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities revenues are from Entergy’s nuclear power plants located in the northern United States. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Most of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in 2022. The PPA prices are for a set price per MWh and escalate each year, up to $61.50 /MWh in 2022. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. Additionally, as the PPA pricing was considered below-market at the time of acquisition, a liability was recorded for the fair value of the below-market PPA, and is being amortized to revenue over the life of the agreement. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues.
Entergy Texas [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenue Recognition Entergy implemented ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” effective January 1, 2018. Topic 606 requires entities to “recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.” The ASU details a five-step model that should be followed to achieve the core principle. This accounting was applied to all contracts using the modified retrospective method, which requires an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date. Because the standard did not result in any material change in how Entergy recognizes revenue, however, no adjustment to retained earnings was required. Similarly, there was no effect on revenues recognized under Topic 606 for the three or nine months ended September 30, 2018. Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the three and nine months ended September 30, 2018 were as follows: 2018 Three Months Ended Nine Months Ended (In Thousands) Utility: Residential $1,138,744 $2,799,539 Commercial 693,760 1,871,380 Industrial 682,823 1,904,828 Governmental 60,647 173,949 Total billed retail 2,575,974 6,749,696 Sales for resale (a) 76,247 214,984 Other electric revenues (b) 42,847 289,668 Non-customer revenues (c) 2,819 22,026 Total electric revenues 2,697,887 7,276,374 Natural gas 26,352 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 407,763 1,148,460 Non-customer revenues (c) (27,683 ) (40,854 ) Total competitive businesses 380,080 1,107,606 Total operating revenues $3,104,319 $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Energy is provided on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. This may result in variability of reported revenues from one period to the next as prior estimates are reversed and new estimates recorded. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as non-customer revenue in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and the City of New Orleans, including Algiers, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities revenues are from Entergy’s nuclear power plants located in the northern United States. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Most of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in 2022. The PPA prices are for a set price per MWh and escalate each year, up to $61.50 /MWh in 2022. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. Additionally, as the PPA pricing was considered below-market at the time of acquisition, a liability was recorded for the fair value of the below-market PPA, and is being amortized to revenue over the life of the agreement. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues.
System Energy [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenue Recognition Entergy implemented ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” effective January 1, 2018. Topic 606 requires entities to “recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.” The ASU details a five-step model that should be followed to achieve the core principle. This accounting was applied to all contracts using the modified retrospective method, which requires an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date. Because the standard did not result in any material change in how Entergy recognizes revenue, however, no adjustment to retained earnings was required. Similarly, there was no effect on revenues recognized under Topic 606 for the three or nine months ended September 30, 2018. Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the three and nine months ended September 30, 2018 were as follows: 2018 Three Months Ended Nine Months Ended (In Thousands) Utility: Residential $1,138,744 $2,799,539 Commercial 693,760 1,871,380 Industrial 682,823 1,904,828 Governmental 60,647 173,949 Total billed retail 2,575,974 6,749,696 Sales for resale (a) 76,247 214,984 Other electric revenues (b) 42,847 289,668 Non-customer revenues (c) 2,819 22,026 Total electric revenues 2,697,887 7,276,374 Natural gas 26,352 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 407,763 1,148,460 Non-customer revenues (c) (27,683 ) (40,854 ) Total competitive businesses 380,080 1,107,606 Total operating revenues $3,104,319 $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Energy is provided on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. This may result in variability of reported revenues from one period to the next as prior estimates are reversed and new estimates recorded. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as non-customer revenue in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and the City of New Orleans, including Algiers, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities revenues are from Entergy’s nuclear power plants located in the northern United States. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Most of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in 2022. The PPA prices are for a set price per MWh and escalate each year, up to $61.50 /MWh in 2022. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. Additionally, as the PPA pricing was considered below-market at the time of acquisition, a liability was recorded for the fair value of the below-market PPA, and is being amortized to revenue over the life of the agreement. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues.

Asset Retirement Obligations As

Asset Retirement Obligations Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2018
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 2018, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in an $85.4 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining life of the unit. As discussed in the Form 10-K, Entergy Wholesale Commodities plant owners will submit filings with the NRC for planned shutdown activities as the nuclear plants individually approach and begin decommissioning. Entergy Nuclear Generation Company expects to file its Post-Shutdown Decommissioning Activities Report (PSDAR) with the NRC in the fourth quarter 2018 for the Pilgrim plant. As part of the development of the PSDAR, Entergy obtained a revised decommissioning cost study in the third quarter 2018. The revised estimate resulted in a $117.5 million increase in the decommissioning cost liability and a corresponding impairment charge. See Note 14 to the financial statements in the Form 10-K for a discussion of impairment of the Pilgrim plant.
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 2018, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in an $85.4 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining life of the unit. As discussed in the Form 10-K, Entergy Wholesale Commodities plant owners will submit filings with the NRC for planned shutdown activities as the nuclear plants individually approach and begin decommissioning. Entergy Nuclear Generation Company expects to file its Post-Shutdown Decommissioning Activities Report (PSDAR) with the NRC in the fourth quarter 2018 for the Pilgrim plant. As part of the development of the PSDAR, Entergy obtained a revised decommissioning cost study in the third quarter 2018. The revised estimate resulted in a $117.5 million increase in the decommissioning cost liability and a corresponding impairment charge. See Note 14 to the financial statements in the Form 10-K for a discussion of impairment of the Pilgrim plant.
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 2018, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in an $85.4 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining life of the unit. As discussed in the Form 10-K, Entergy Wholesale Commodities plant owners will submit filings with the NRC for planned shutdown activities as the nuclear plants individually approach and begin decommissioning. Entergy Nuclear Generation Company expects to file its Post-Shutdown Decommissioning Activities Report (PSDAR) with the NRC in the fourth quarter 2018 for the Pilgrim plant. As part of the development of the PSDAR, Entergy obtained a revised decommissioning cost study in the third quarter 2018. The revised estimate resulted in a $117.5 million increase in the decommissioning cost liability and a corresponding impairment charge. See Note 14 to the financial statements in the Form 10-K for a discussion of impairment of the Pilgrim plant.
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 2018, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in an $85.4 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining life of the unit. As discussed in the Form 10-K, Entergy Wholesale Commodities plant owners will submit filings with the NRC for planned shutdown activities as the nuclear plants individually approach and begin decommissioning. Entergy Nuclear Generation Company expects to file its Post-Shutdown Decommissioning Activities Report (PSDAR) with the NRC in the fourth quarter 2018 for the Pilgrim plant. As part of the development of the PSDAR, Entergy obtained a revised decommissioning cost study in the third quarter 2018. The revised estimate resulted in a $117.5 million increase in the decommissioning cost liability and a corresponding impairment charge. See Note 14 to the financial statements in the Form 10-K for a discussion of impairment of the Pilgrim plant.
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 2018, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in an $85.4 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining life of the unit. As discussed in the Form 10-K, Entergy Wholesale Commodities plant owners will submit filings with the NRC for planned shutdown activities as the nuclear plants individually approach and begin decommissioning. Entergy Nuclear Generation Company expects to file its Post-Shutdown Decommissioning Activities Report (PSDAR) with the NRC in the fourth quarter 2018 for the Pilgrim plant. As part of the development of the PSDAR, Entergy obtained a revised decommissioning cost study in the third quarter 2018. The revised estimate resulted in a $117.5 million increase in the decommissioning cost liability and a corresponding impairment charge. See Note 14 to the financial statements in the Form 10-K for a discussion of impairment of the Pilgrim plant.
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 2018, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in an $85.4 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining life of the unit. As discussed in the Form 10-K, Entergy Wholesale Commodities plant owners will submit filings with the NRC for planned shutdown activities as the nuclear plants individually approach and begin decommissioning. Entergy Nuclear Generation Company expects to file its Post-Shutdown Decommissioning Activities Report (PSDAR) with the NRC in the fourth quarter 2018 for the Pilgrim plant. As part of the development of the PSDAR, Entergy obtained a revised decommissioning cost study in the third quarter 2018. The revised estimate resulted in a $117.5 million increase in the decommissioning cost liability and a corresponding impairment charge. See Note 14 to the financial statements in the Form 10-K for a discussion of impairment of the Pilgrim plant.
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 2018, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in an $85.4 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining life of the unit. As discussed in the Form 10-K, Entergy Wholesale Commodities plant owners will submit filings with the NRC for planned shutdown activities as the nuclear plants individually approach and begin decommissioning. Entergy Nuclear Generation Company expects to file its Post-Shutdown Decommissioning Activities Report (PSDAR) with the NRC in the fourth quarter 2018 for the Pilgrim plant. As part of the development of the PSDAR, Entergy obtained a revised decommissioning cost study in the third quarter 2018. The revised estimate resulted in a $117.5 million increase in the decommissioning cost liability and a corresponding impairment charge. See Note 14 to the financial statements in the Form 10-K for a discussion of impairment of the Pilgrim plant.

Rate And Regulatory Matters Rat

Rate And Regulatory Matters Rate and Regulatory Matters (Tables)	9 Months Ended
	Sep. 30, 2018
Entergy Arkansas [Member]
System Agreement Cost Equalization Payments (Receipts) Among Utility Operating Companies [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
Rough Production Cost Equalization Payments (Receipts) Among Utility Operating Companies [Table Text Block]	Entergy filed in May 2018 the bandwidth true-up payments and receipts for the 2011-2014 rate filings (table does not net to zero due to rounding): Payments (Receipts) (In Millions) Entergy Arkansas $3 Entergy Louisiana $3 Entergy Mississippi ($1) Entergy New Orleans $1 Entergy Texas ($5)
Entergy Louisiana [Member]
System Agreement Cost Equalization Payments (Receipts) Among Utility Operating Companies [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
Rough Production Cost Equalization Payments (Receipts) Among Utility Operating Companies [Table Text Block]	Entergy filed in May 2018 the bandwidth true-up payments and receipts for the 2011-2014 rate filings (table does not net to zero due to rounding): Payments (Receipts) (In Millions) Entergy Arkansas $3 Entergy Louisiana $3 Entergy Mississippi ($1) Entergy New Orleans $1 Entergy Texas ($5)
Entergy Mississippi [Member]
System Agreement Cost Equalization Payments (Receipts) Among Utility Operating Companies [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
Rough Production Cost Equalization Payments (Receipts) Among Utility Operating Companies [Table Text Block]	Entergy filed in May 2018 the bandwidth true-up payments and receipts for the 2011-2014 rate filings (table does not net to zero due to rounding): Payments (Receipts) (In Millions) Entergy Arkansas $3 Entergy Louisiana $3 Entergy Mississippi ($1) Entergy New Orleans $1 Entergy Texas ($5)
Entergy New Orleans [Member]
System Agreement Cost Equalization Payments (Receipts) Among Utility Operating Companies [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
Rough Production Cost Equalization Payments (Receipts) Among Utility Operating Companies [Table Text Block]	Entergy filed in May 2018 the bandwidth true-up payments and receipts for the 2011-2014 rate filings (table does not net to zero due to rounding): Payments (Receipts) (In Millions) Entergy Arkansas $3 Entergy Louisiana $3 Entergy Mississippi ($1) Entergy New Orleans $1 Entergy Texas ($5)
Entergy Texas [Member]
System Agreement Cost Equalization Payments (Receipts) Among Utility Operating Companies [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
Rough Production Cost Equalization Payments (Receipts) Among Utility Operating Companies [Table Text Block]	Entergy filed in May 2018 the bandwidth true-up payments and receipts for the 2011-2014 rate filings (table does not net to zero due to rounding): Payments (Receipts) (In Millions) Entergy Arkansas $3 Entergy Louisiana $3 Entergy Mississippi ($1) Entergy New Orleans $1 Entergy Texas ($5)

Equity (Tables)

Equity (Tables)	9 Months Ended
	Sep. 30, 2018
Schedule Of Earnings Per Share Basic And Diluted	The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Three Months Ended September 30, 2018 2017 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $536.4 181.0 $2.96 $398.2 179.6 $2.22 Average dilutive effect of: Stock options 0.4 (0.01 ) 0.2 — Other equity plans 0.8 (0.01 ) 0.7 (0.01 ) Equity forwards 1.5 (0.02 ) — — Diluted earnings per share $536.4 183.7 $2.92 $398.2 180.5 $2.21 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.1 million for the three months ended September 30, 2018 and approximately 2.5 million for the three months ended September 30, 2017 . For the Nine Months Ended September 30, 2018 2017 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $914.6 180.8 $5.06 $890.7 179.5 $4.96 Average dilutive effect of: Stock options 0.3 (0.01 ) 0.2 (0.01 ) Other equity plans 0.7 (0.01 ) 0.5 (0.01 ) Equity forwards 0.9 (0.03 ) — — Diluted earnings per share $914.6 182.7 $5.01 $890.7 180.2 $4.94
Schedule of Accumulated Other Comprehensive Income (Loss)	Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, July 1, 2018 ($14,874 ) ($589,926 ) ($8,842 ) ($613,642 ) Other comprehensive income (loss) before reclassifications (40,401 ) — (7,173 ) (47,574 ) Amounts reclassified from accumulated other comprehensive income (loss) 8,397 15,265 5,428 29,090 Net other comprehensive income (loss) for the period (32,004 ) 15,265 (1,745 ) (18,484 ) Ending balance, September 30, 2018 ($46,878 ) ($574,661 ) ($10,587 ) ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2017 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, July 1, 2017 $23,414 ($449,898 ) $479,257 $52,773 Other comprehensive income (loss) before reclassifications 27,884 — 35,630 63,514 Amounts reclassified from accumulated other comprehensive income (loss) (14,671 ) 12,297 (2,235 ) (4,609 ) Net other comprehensive income (loss) for the period 13,213 12,297 33,395 58,905 Ending balance, September 30, 2017 $36,627 ($437,601 ) $512,652 $111,678 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Ending balance, December 31, 2017 ($37,477 ) ($531,099 ) $545,045 ($23,531 ) Implementation of accounting standards — — (632,617 ) (632,617 ) Beginning balance, January 1, 2018 ($37,477 ) ($531,099 ) ($87,572 ) ($656,148 ) Other comprehensive income (loss) before reclassifications (31,816 ) — (50,958 ) (82,774 ) Amounts reclassified from accumulated other comprehensive income (loss) 30,171 47,404 13,716 91,291 Net other comprehensive income (loss) for the period (1,645 ) 47,404 (37,242 ) 8,517 Reclassification pursuant to ASU 2018-02 (7,756 ) (90,966 ) 114,227 15,505 Ending balance, September 30, 2018 ($46,878 ) ($574,661 ) ($10,587 ) ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2017 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, January 1, 2017 $3,993 ($469,446 ) $429,734 $748 ($34,971 ) Other comprehensive income (loss) before reclassifications 88,550 — 109,372 (748 ) 197,174 Amounts reclassified from accumulated other comprehensive income (loss) (55,916 ) 31,845 (26,454 ) — (50,525 ) Net other comprehensive income (loss) for the period 32,634 31,845 82,918 (748 ) 146,649 Ending balance, September 30, 2017 $36,627 ($437,601 ) $512,652 $— $111,678
Reclassification out of Accumulated Other Comprehensive Income	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended September 30, 2018 and 2017 are as follows: Amounts reclassified Income Statement Location 2018 2017 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts ($10,566 ) $22,756 Competitive business operating revenues Interest rate swaps (63 ) (185 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges (10,629 ) 22,571 2,232 (7,900 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) ($8,397 ) $14,671 Pension and other postretirement liabilities Amortization of prior-service credit $5,425 $6,565 (a) Amortization of loss (24,740 ) (21,480 ) (a) Settlement loss (76 ) (4,200 ) (a) Total amortization (19,391 ) (19,115 ) 4,126 6,818 Income taxes Total amortization (net of tax) ($15,265 ) ($12,297 ) Net unrealized investment gain (loss) Realized gain (loss) ($8,589 ) $4,382 Interest and investment income 3,161 (2,147 ) Income taxes Total realized investment gain (loss) (net of tax) ($5,428 ) $2,235 Total reclassifications for the period (net of tax) ($29,090 ) $4,609 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the nine months ended September 30, 2018 and 2017 are as follows: Amounts reclassified from AOCI Income Statement Location 2018 2017 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts ($37,913 ) $86,678 Competitive business operating revenues Interest rate swaps (278 ) (654 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges (38,191 ) 86,024 8,020 (30,108 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) ($30,171 ) $55,916 Pension and other postretirement liabilities Amortization of prior-service credit $16,278 $19,691 (a) Amortization of loss (74,503 ) (64,605 ) (a) Settlement loss (2,098 ) (5,965 ) (a) Total amortization (60,323 ) (50,879 ) 12,919 19,034 Income taxes Total amortization (net of tax) ($47,404 ) ($31,845 ) Net unrealized investment gain (loss) Realized gain (loss) ($21,703 ) $51,871 Interest and investment income 7,987 (25,417 ) Income taxes Total realized investment gain (loss) (net of tax) ($13,716 ) $26,454 Total reclassifications for the period (net of tax) ($91,291 ) $50,525 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.
Entergy Louisiana [Member]
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2018 and 2017: Pension and Other 2018 2017 (In Thousands) Beginning balance, July 1, ($57,451 ) ($49,122 ) Amounts reclassified from accumulated other (500 ) (370 ) Net other comprehensive income (loss) for the period (500 ) (370 ) Ending balance, September 30, ($57,951 ) ($49,492 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2018 and 2017: Pension and Other 2018 2017 (In Thousands) Beginning balance, January 1, ($46,400 ) ($48,442 ) Amounts reclassified from accumulated other (1,502 ) (1,050 ) Net other comprehensive income (loss) for the period (1,502 ) (1,050 ) Reclassification pursuant to ASU 2018-02 (10,049 ) — Ending balance, September 30, ($57,951 ) ($49,492 )
Reclassification out of Accumulated Other Comprehensive Income	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended September 30, 2018 and 2017 are as follows: Amounts reclassified Income Statement Location 2018 2017 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,934 $1,934 (a) Amortization of loss (1,257 ) (1,332 ) (a) Total amortization 677 602 (177 ) (232 ) Income taxes Total amortization (net of tax) 500 370 Total reclassifications for the period (net of tax) $500 $370 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the nine months ended September 30, 2018 and 2017 are as follows: Amounts reclassified Income Statement Location 2018 2017 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,802 $5,802 (a) Amortization of loss (3,770 ) (3,996 ) (a) Total amortization 2,032 1,806 (530 ) (756 ) Income taxes Total amortization (net of tax) 1,502 1,050 Total reclassifications for the period (net of tax) $1,502 $1,050 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.

Revolving Credit Facilities, _2

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2018
Summary Of The Borrowings Outstanding And Capacity Available Under The Facility	Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $630 $6 $2,864
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2018 Letters of Credit Outstanding as of September 30, 2018 Entergy Arkansas April 2019 $20 million (b) 3.49% $— $— Entergy Arkansas September 2023 $150 million (c) 3.49% $— $— Entergy Louisiana September 2023 $350 million (c) 3.49% $— $— Entergy Mississippi May 2019 $37.5 million (d) 3.74% $— $— Entergy Mississippi May 2019 $35 million (d) 3.74% $— $— Entergy Mississippi May 2019 $10 million (d) 3.74% $— $— Entergy New Orleans November 2018 $25 million (c) 3.72% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.74% $— $1.3 million (a) For credit facilities with no borrowings as of September 30, 2018, the interest rate is the estimated interest rate as of September 30, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $22 million Entergy Mississippi $40 million 0.70% $11.2 million Entergy New Orleans $15 million 1.00% $2.1 million Entergy Texas $50 million 0.70% $20 million (a) As of September 30, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 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 September 30, 2018 (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 $34 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2018 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.18% $70.4 Entergy Louisiana River Bend VIE September 2021 $105 3.18% $34.5 Entergy Louisiana Waterford VIE September 2021 $105 3.18% $30.5 System Energy VIE September 2021 $120 3.18% $37.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2018 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 3.78% Series I due October 2018 $85 million System Energy VIE 3.42% Series J due April 2021 $100 million
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,515,836 $16,232,180 Entergy Arkansas $3,242,282 $3,031,681 Entergy Louisiana $6,761,123 $6,757,649 Entergy Mississippi $1,270,830 $1,234,124 Entergy New Orleans $491,570 $499,764 Entergy Texas $1,527,817 $1,546,101 System Energy $639,455 $610,485 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $186 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, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Arkansas [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2018 Letters of Credit Outstanding as of September 30, 2018 Entergy Arkansas April 2019 $20 million (b) 3.49% $— $— Entergy Arkansas September 2023 $150 million (c) 3.49% $— $— Entergy Louisiana September 2023 $350 million (c) 3.49% $— $— Entergy Mississippi May 2019 $37.5 million (d) 3.74% $— $— Entergy Mississippi May 2019 $35 million (d) 3.74% $— $— Entergy Mississippi May 2019 $10 million (d) 3.74% $— $— Entergy New Orleans November 2018 $25 million (c) 3.72% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.74% $— $1.3 million (a) For credit facilities with no borrowings as of September 30, 2018, the interest rate is the estimated interest rate as of September 30, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $22 million Entergy Mississippi $40 million 0.70% $11.2 million Entergy New Orleans $15 million 1.00% $2.1 million Entergy Texas $50 million 0.70% $20 million (a) As of September 30, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 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 September 30, 2018 (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 $34 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2018 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.18% $70.4 Entergy Louisiana River Bend VIE September 2021 $105 3.18% $34.5 Entergy Louisiana Waterford VIE September 2021 $105 3.18% $30.5 System Energy VIE September 2021 $120 3.18% $37.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2018 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 3.78% Series I due October 2018 $85 million System Energy VIE 3.42% Series J due April 2021 $100 million
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,515,836 $16,232,180 Entergy Arkansas $3,242,282 $3,031,681 Entergy Louisiana $6,761,123 $6,757,649 Entergy Mississippi $1,270,830 $1,234,124 Entergy New Orleans $491,570 $499,764 Entergy Texas $1,527,817 $1,546,101 System Energy $639,455 $610,485 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $186 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, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Louisiana [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2018 Letters of Credit Outstanding as of September 30, 2018 Entergy Arkansas April 2019 $20 million (b) 3.49% $— $— Entergy Arkansas September 2023 $150 million (c) 3.49% $— $— Entergy Louisiana September 2023 $350 million (c) 3.49% $— $— Entergy Mississippi May 2019 $37.5 million (d) 3.74% $— $— Entergy Mississippi May 2019 $35 million (d) 3.74% $— $— Entergy Mississippi May 2019 $10 million (d) 3.74% $— $— Entergy New Orleans November 2018 $25 million (c) 3.72% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.74% $— $1.3 million (a) For credit facilities with no borrowings as of September 30, 2018, the interest rate is the estimated interest rate as of September 30, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $22 million Entergy Mississippi $40 million 0.70% $11.2 million Entergy New Orleans $15 million 1.00% $2.1 million Entergy Texas $50 million 0.70% $20 million (a) As of September 30, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 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 September 30, 2018 (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 $34 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2018 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.18% $70.4 Entergy Louisiana River Bend VIE September 2021 $105 3.18% $34.5 Entergy Louisiana Waterford VIE September 2021 $105 3.18% $30.5 System Energy VIE September 2021 $120 3.18% $37.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2018 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 3.78% Series I due October 2018 $85 million System Energy VIE 3.42% Series J due April 2021 $100 million
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,515,836 $16,232,180 Entergy Arkansas $3,242,282 $3,031,681 Entergy Louisiana $6,761,123 $6,757,649 Entergy Mississippi $1,270,830 $1,234,124 Entergy New Orleans $491,570 $499,764 Entergy Texas $1,527,817 $1,546,101 System Energy $639,455 $610,485 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $186 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, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Mississippi [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2018 Letters of Credit Outstanding as of September 30, 2018 Entergy Arkansas April 2019 $20 million (b) 3.49% $— $— Entergy Arkansas September 2023 $150 million (c) 3.49% $— $— Entergy Louisiana September 2023 $350 million (c) 3.49% $— $— Entergy Mississippi May 2019 $37.5 million (d) 3.74% $— $— Entergy Mississippi May 2019 $35 million (d) 3.74% $— $— Entergy Mississippi May 2019 $10 million (d) 3.74% $— $— Entergy New Orleans November 2018 $25 million (c) 3.72% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.74% $— $1.3 million (a) For credit facilities with no borrowings as of September 30, 2018, the interest rate is the estimated interest rate as of September 30, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $22 million Entergy Mississippi $40 million 0.70% $11.2 million Entergy New Orleans $15 million 1.00% $2.1 million Entergy Texas $50 million 0.70% $20 million (a) As of September 30, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 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 September 30, 2018 (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 $34 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,515,836 $16,232,180 Entergy Arkansas $3,242,282 $3,031,681 Entergy Louisiana $6,761,123 $6,757,649 Entergy Mississippi $1,270,830 $1,234,124 Entergy New Orleans $491,570 $499,764 Entergy Texas $1,527,817 $1,546,101 System Energy $639,455 $610,485 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $186 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, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy New Orleans [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2018 Letters of Credit Outstanding as of September 30, 2018 Entergy Arkansas April 2019 $20 million (b) 3.49% $— $— Entergy Arkansas September 2023 $150 million (c) 3.49% $— $— Entergy Louisiana September 2023 $350 million (c) 3.49% $— $— Entergy Mississippi May 2019 $37.5 million (d) 3.74% $— $— Entergy Mississippi May 2019 $35 million (d) 3.74% $— $— Entergy Mississippi May 2019 $10 million (d) 3.74% $— $— Entergy New Orleans November 2018 $25 million (c) 3.72% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.74% $— $1.3 million (a) For credit facilities with no borrowings as of September 30, 2018, the interest rate is the estimated interest rate as of September 30, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $22 million Entergy Mississippi $40 million 0.70% $11.2 million Entergy New Orleans $15 million 1.00% $2.1 million Entergy Texas $50 million 0.70% $20 million (a) As of September 30, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 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 September 30, 2018 (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 $34 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,515,836 $16,232,180 Entergy Arkansas $3,242,282 $3,031,681 Entergy Louisiana $6,761,123 $6,757,649 Entergy Mississippi $1,270,830 $1,234,124 Entergy New Orleans $491,570 $499,764 Entergy Texas $1,527,817 $1,546,101 System Energy $639,455 $610,485 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $186 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, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Texas [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2018 Letters of Credit Outstanding as of September 30, 2018 Entergy Arkansas April 2019 $20 million (b) 3.49% $— $— Entergy Arkansas September 2023 $150 million (c) 3.49% $— $— Entergy Louisiana September 2023 $350 million (c) 3.49% $— $— Entergy Mississippi May 2019 $37.5 million (d) 3.74% $— $— Entergy Mississippi May 2019 $35 million (d) 3.74% $— $— Entergy Mississippi May 2019 $10 million (d) 3.74% $— $— Entergy New Orleans November 2018 $25 million (c) 3.72% $— $0.8 million Entergy Texas September 2023 $150 million (c) 3.74% $— $1.3 million (a) For credit facilities with no borrowings as of September 30, 2018, the interest rate is the estimated interest rate as of September 30, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $22 million Entergy Mississippi $40 million 0.70% $11.2 million Entergy New Orleans $15 million 1.00% $2.1 million Entergy Texas $50 million 0.70% $20 million (a) As of September 30, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 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 September 30, 2018 (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 $34 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,515,836 $16,232,180 Entergy Arkansas $3,242,282 $3,031,681 Entergy Louisiana $6,761,123 $6,757,649 Entergy Mississippi $1,270,830 $1,234,124 Entergy New Orleans $491,570 $499,764 Entergy Texas $1,527,817 $1,546,101 System Energy $639,455 $610,485 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $186 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, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
System Energy [Member]
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2018 (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 $34 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of September 30, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2018 (Dollars in Millions) Entergy Arkansas VIE September 2021 $80 3.18% $70.4 Entergy Louisiana River Bend VIE September 2021 $105 3.18% $34.5 Entergy Louisiana Waterford VIE September 2021 $105 3.18% $30.5 System Energy VIE September 2021 $120 3.18% $37.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2018 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 3.78% Series I due October 2018 $85 million System Energy VIE 3.42% Series J due April 2021 $100 million
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,515,836 $16,232,180 Entergy Arkansas $3,242,282 $3,031,681 Entergy Louisiana $6,761,123 $6,757,649 Entergy Mississippi $1,270,830 $1,234,124 Entergy New Orleans $491,570 $499,764 Entergy Texas $1,527,817 $1,546,101 System Energy $639,455 $610,485 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $186 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, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 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)	9 Months Ended
	Sep. 30, 2018
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Financial Information For Stock Options	The following table includes financial information for outstanding stock options for the three months ended September 30, 2018 and 2017 : 2018 2017 (In Millions) Compensation expense included in Entergy’s net income $1.1 $1.1 Tax benefit recognized in Entergy’s net income $0.2 $0.5 Compensation cost capitalized as part of fixed assets and inventory $0.1 $0.2 The following table includes financial information for outstanding stock options for the nine months ended September 30, 2018 and 2017 : 2018 2017 (In Millions) Compensation expense included in Entergy’s net income $3.3 $3.3 Tax benefit recognized in Entergy’s net income $0.8 $1.3 Compensation cost capitalized as part of fixed assets and inventory $0.5 $0.6
Financial Information For Restricted Stock	The following table includes financial information for other outstanding equity awards for the three months ended September 30, 2018 and 2017: 2018 2017 (In Millions) Compensation expense included in Entergy’s net income $8.5 $7.6 Tax benefit recognized in Entergy’s net income $2.2 $3.0 Compensation cost capitalized as part of fixed assets and inventory $2.5 $2.1 The following table includes financial information for other outstanding equity awards for the nine months ended September 30, 2018 and 2017 : 2018 2017 (In Millions) Compensation expense included in Entergy’s net income $26.0 $24.1 Tax benefit recognized in Entergy’s net income $6.6 $9.3 Compensation cost capitalized as part of fixed assets and inventory $7.3 $6.3

Retirement And Other Postreti_2

Retirement And Other Postretirement Benefits (Tables)	9 Months Ended
	Sep. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Reclassification out of Accumulated Other Comprehensive Income, amortization	Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($71 ) $5,425 Amortization of loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($88 ) $6,565 Amortization of loss (18,451 ) (2,202 ) (827 ) (21,480 ) Settlement loss — — (4,200 ) (4,200 ) ($18,516 ) $4,516 ($5,115 ) ($19,115 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($297 ) $16,786 ($211 ) $16,278 Amortization of loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($195 ) $20,152 ($266 ) $19,691 Amortization of loss (55,351 ) (6,606 ) (2,648 ) (64,605 ) Settlement loss — — (5,965 ) (5,965 ) ($55,546 ) $13,546 ($8,879 ) ($50,879 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,594 ) (1,395 ) (7 ) (3,996 ) ($2,594 ) $4,407 ($7 ) $1,806
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $116,256 $100,230 Interest cost on projected benefit obligation 200,562 195,618 Expected return on assets (331,605 ) (306,168 ) Amortization of prior service cost 297 195 Amortization of loss 205,578 170,790 Net pension costs $191,088 $160,665
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 third quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $20,346 $20,187 Interest cost on accumulated postretirement benefit obligation (APBO) 38,043 41,880 Expected return on assets (31,119 ) (28,224 ) Amortization of prior service credit (27,753 ) (31,068 ) Amortization of loss 10,296 16,428 Net other postretirement benefit cost $9,813 $19,203
Entergy Arkansas [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 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 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projects benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,270 $20,775 $4,416 $1,875 $4,092 $4,608 Interest cost on projected benefit obligation 38,832 44,427 11,196 5,373 10,176 9,273 Expected return on assets (61,281 ) (69,051 ) (18,393 ) (8,400 ) (18,540 ) (13,989 ) Amortization of loss 34,920 37,062 9,159 4,974 6,930 8,892 Net pension cost $27,741 $33,213 $6,378 $3,822 $2,658 $8,784
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,919 $14,933 $7,250 $10,883 $13,786 Pension contributions made through September 2018 $51,982 $58,363 $12,203 $5,938 $9,323 $11,152 Remaining estimated pension contributions to be made in 2018 $12,080 $13,556 $2,730 $1,312 $1,560 $2,634
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 the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,589 $4,779 $870 $426 $1,116 $960 Interest cost on APBO 6,765 9,075 2,070 1,407 3,372 1,677 Expected return on assets (11,877 ) — (3,600 ) (3,477 ) (6,540 ) (2,151 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 3,345 1,395 1,257 315 2,478 1,170 Net other postretirement benefit cost ($3,012 ) $9,447 ($771 ) ($1,887 ) ($1,311 ) $522
Entergy Arkansas [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $114 $42 $73 $20 $122 2017 $111 $46 $62 $18 $124 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarters of 2018 and 2017, were settlement charges of $7 thousand and $10 thousand , 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 nine months ended September 30, 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $369 $138 $230 $62 $529 2017 $483 $141 $189 $55 $377
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Reclassification out of Accumulated Other Comprehensive Income, amortization	Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($71 ) $5,425 Amortization of loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($88 ) $6,565 Amortization of loss (18,451 ) (2,202 ) (827 ) (21,480 ) Settlement loss — — (4,200 ) (4,200 ) ($18,516 ) $4,516 ($5,115 ) ($19,115 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($297 ) $16,786 ($211 ) $16,278 Amortization of loss (65,870 ) (5,801 ) (2,832 ) (74,503 ) Settlement loss — — (2,098 ) (2,098 ) ($66,167 ) $10,985 ($5,141 ) ($60,323 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,601 ) (1,164 ) (5 ) (3,770 ) ($2,601 ) $4,638 ($5 ) $2,032 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($195 ) $20,152 ($266 ) $19,691 Amortization of loss (55,351 ) (6,606 ) (2,648 ) (64,605 ) Settlement loss — — (5,965 ) (5,965 ) ($55,546 ) $13,546 ($8,879 ) ($50,879 ) Entergy Louisiana Amortization of prior service credit $— $5,802 $— $5,802 Amortization of loss (2,594 ) (1,395 ) (7 ) (3,996 ) ($2,594 ) $4,407 ($7 ) $1,806
Entergy Louisiana [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 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 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projects benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,270 $20,775 $4,416 $1,875 $4,092 $4,608 Interest cost on projected benefit obligation 38,832 44,427 11,196 5,373 10,176 9,273 Expected return on assets (61,281 ) (69,051 ) (18,393 ) (8,400 ) (18,540 ) (13,989 ) Amortization of loss 34,920 37,062 9,159 4,974 6,930 8,892 Net pension cost $27,741 $33,213 $6,378 $3,822 $2,658 $8,784
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,919 $14,933 $7,250 $10,883 $13,786 Pension contributions made through September 2018 $51,982 $58,363 $12,203 $5,938 $9,323 $11,152 Remaining estimated pension contributions to be made in 2018 $12,080 $13,556 $2,730 $1,312 $1,560 $2,634
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 the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,589 $4,779 $870 $426 $1,116 $960 Interest cost on APBO 6,765 9,075 2,070 1,407 3,372 1,677 Expected return on assets (11,877 ) — (3,600 ) (3,477 ) (6,540 ) (2,151 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 3,345 1,395 1,257 315 2,478 1,170 Net other postretirement benefit cost ($3,012 ) $9,447 ($771 ) ($1,887 ) ($1,311 ) $522
Entergy Louisiana [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $114 $42 $73 $20 $122 2017 $111 $46 $62 $18 $124 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarters of 2018 and 2017, were settlement charges of $7 thousand and $10 thousand , 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 nine months ended September 30, 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $369 $138 $230 $62 $529 2017 $483 $141 $189 $55 $377
Entergy Mississippi [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 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 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projects benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,270 $20,775 $4,416 $1,875 $4,092 $4,608 Interest cost on projected benefit obligation 38,832 44,427 11,196 5,373 10,176 9,273 Expected return on assets (61,281 ) (69,051 ) (18,393 ) (8,400 ) (18,540 ) (13,989 ) Amortization of loss 34,920 37,062 9,159 4,974 6,930 8,892 Net pension cost $27,741 $33,213 $6,378 $3,822 $2,658 $8,784
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,919 $14,933 $7,250 $10,883 $13,786 Pension contributions made through September 2018 $51,982 $58,363 $12,203 $5,938 $9,323 $11,152 Remaining estimated pension contributions to be made in 2018 $12,080 $13,556 $2,730 $1,312 $1,560 $2,634
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 the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,589 $4,779 $870 $426 $1,116 $960 Interest cost on APBO 6,765 9,075 2,070 1,407 3,372 1,677 Expected return on assets (11,877 ) — (3,600 ) (3,477 ) (6,540 ) (2,151 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 3,345 1,395 1,257 315 2,478 1,170 Net other postretirement benefit cost ($3,012 ) $9,447 ($771 ) ($1,887 ) ($1,311 ) $522
Entergy Mississippi [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $114 $42 $73 $20 $122 2017 $111 $46 $62 $18 $124 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarters of 2018 and 2017, were settlement charges of $7 thousand and $10 thousand , 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 nine months ended September 30, 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $369 $138 $230 $62 $529 2017 $483 $141 $189 $55 $377
Entergy New Orleans [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 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 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projects benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,270 $20,775 $4,416 $1,875 $4,092 $4,608 Interest cost on projected benefit obligation 38,832 44,427 11,196 5,373 10,176 9,273 Expected return on assets (61,281 ) (69,051 ) (18,393 ) (8,400 ) (18,540 ) (13,989 ) Amortization of loss 34,920 37,062 9,159 4,974 6,930 8,892 Net pension cost $27,741 $33,213 $6,378 $3,822 $2,658 $8,784
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,919 $14,933 $7,250 $10,883 $13,786 Pension contributions made through September 2018 $51,982 $58,363 $12,203 $5,938 $9,323 $11,152 Remaining estimated pension contributions to be made in 2018 $12,080 $13,556 $2,730 $1,312 $1,560 $2,634
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 the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,589 $4,779 $870 $426 $1,116 $960 Interest cost on APBO 6,765 9,075 2,070 1,407 3,372 1,677 Expected return on assets (11,877 ) — (3,600 ) (3,477 ) (6,540 ) (2,151 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 3,345 1,395 1,257 315 2,478 1,170 Net other postretirement benefit cost ($3,012 ) $9,447 ($771 ) ($1,887 ) ($1,311 ) $522
Entergy New Orleans [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $114 $42 $73 $20 $122 2017 $111 $46 $62 $18 $124 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarters of 2018 and 2017, were settlement charges of $7 thousand and $10 thousand , 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 nine months ended September 30, 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $369 $138 $230 $62 $529 2017 $483 $141 $189 $55 $377
Entergy Texas [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 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 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projects benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,270 $20,775 $4,416 $1,875 $4,092 $4,608 Interest cost on projected benefit obligation 38,832 44,427 11,196 5,373 10,176 9,273 Expected return on assets (61,281 ) (69,051 ) (18,393 ) (8,400 ) (18,540 ) (13,989 ) Amortization of loss 34,920 37,062 9,159 4,974 6,930 8,892 Net pension cost $27,741 $33,213 $6,378 $3,822 $2,658 $8,784
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,919 $14,933 $7,250 $10,883 $13,786 Pension contributions made through September 2018 $51,982 $58,363 $12,203 $5,938 $9,323 $11,152 Remaining estimated pension contributions to be made in 2018 $12,080 $13,556 $2,730 $1,312 $1,560 $2,634
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 the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,589 $4,779 $870 $426 $1,116 $960 Interest cost on APBO 6,765 9,075 2,070 1,407 3,372 1,677 Expected return on assets (11,877 ) — (3,600 ) (3,477 ) (6,540 ) (2,151 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 3,345 1,395 1,257 315 2,478 1,170 Net other postretirement benefit cost ($3,012 ) $9,447 ($771 ) ($1,887 ) ($1,311 ) $522
Entergy Texas [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $114 $42 $73 $20 $122 2017 $111 $46 $62 $18 $124 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarters of 2018 and 2017, were settlement charges of $7 thousand and $10 thousand , 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 nine months ended September 30, 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $369 $138 $230 $62 $529 2017 $483 $141 $189 $55 $377
System Energy [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 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 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $18,567 $25,338 $5,466 $2,019 $4,767 $5,328 Interest cost on projects benefit obligation 39,012 44,820 11,307 5,439 10,044 9,681 Expected return on assets (65,553 ) (74,427 ) (19,506 ) (8,979 ) (19,569 ) (14,973 ) Amortization of loss 40,236 43,350 10,830 5,862 7,878 11,145 Net pension cost $32,262 $39,081 $8,097 $4,341 $3,120 $11,181 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,270 $20,775 $4,416 $1,875 $4,092 $4,608 Interest cost on projected benefit obligation 38,832 44,427 11,196 5,373 10,176 9,273 Expected return on assets (61,281 ) (69,051 ) (18,393 ) (8,400 ) (18,540 ) (13,989 ) Amortization of loss 34,920 37,062 9,159 4,974 6,930 8,892 Net pension cost $27,741 $33,213 $6,378 $3,822 $2,658 $8,784
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,919 $14,933 $7,250 $10,883 $13,786 Pension contributions made through September 2018 $51,982 $58,363 $12,203 $5,938 $9,323 $11,152 Remaining estimated pension contributions to be made in 2018 $12,080 $13,556 $2,730 $1,312 $1,560 $2,634
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 the third quarters of 2018 and 2017, included the following components: 2018 Entergy Entergy Entergy Entergy Entergy System (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 loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,379 $4,668 $963 $387 $990 $918 Interest cost on APBO 5,991 8,367 2,049 1,251 2,817 1,500 Expected return on assets (13,026 ) — (3,909 ) (3,939 ) (7,338 ) (2,349 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 867 1,164 1,131 102 618 699 Net other postretirement benefit cost ($7,623 ) $8,397 ($1,134 ) ($2,757 ) ($4,650 ) ($366 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,589 $4,779 $870 $426 $1,116 $960 Interest cost on APBO 6,765 9,075 2,070 1,407 3,372 1,677 Expected return on assets (11,877 ) — (3,600 ) (3,477 ) (6,540 ) (2,151 ) Amortization of prior service credit (3,834 ) (5,802 ) (1,368 ) (558 ) (1,737 ) (1,134 ) Amortization of loss 3,345 1,395 1,257 315 2,478 1,170 Net other postretirement benefit cost ($3,012 ) $9,447 ($771 ) ($1,887 ) ($1,311 ) $522

Business Segment Information (T

Business Segment Information (Tables)	9 Months Ended
	Sep. 30, 2018
Segment Financial Information	Entergy’s segment financial information for the third quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,724,279 $380,080 $— ($40 ) $3,104,319 Income taxes ($137,035 ) ($135,659 ) ($10,312 ) $— ($283,006 ) Consolidated net income (loss) $507,745 $105,571 ($41,601 ) ($31,897 ) $539,818 2017 Operating revenues $2,820,421 $423,245 $— ($38 ) $3,243,628 Income taxes $230,647 $25,563 ($14,415 ) $— $241,795 Consolidated net income (loss) $403,733 $55,765 ($25,956 ) ($31,898 ) $401,644 Entergy’s segment financial information for the nine months ended September 30, 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $7,389,477 $1,107,606 $— ($113 ) $8,496,970 Income taxes ($325,134 ) ($166,882 ) ($27,921 ) $— ($519,937 ) Consolidated net income (loss) $1,104,078 $31,456 ($114,962 ) ($95,695 ) $924,877 Total assets as of September 30, 2018 $44,889,498 $5,507,013 $1,274,909 ($3,200,248 ) $48,471,172 2017 Operating revenues $7,156,865 $1,293,867 $— ($96 ) $8,450,636 Income taxes $459,990 ($507,719 ) ($39,826 ) $— ($87,555 ) Consolidated net income (loss) $817,738 $252,455 ($73,434 ) ($95,695 ) $901,064 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.
Restructuring and Related Costs [Table Text Block]	Total restructuring charges for the third quarters of 2018 and 2017 were comprised of the following: 2018 2017 Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of July 1, $143 $14 $157 $36 $21 $57 Restructuring costs accrued 43 — 43 23 — 23 Non-cash portion — — — — (7 ) (7 ) Balance as of September 30, $186 $14 $200 $59 $14 $73 In addition, Entergy incurred $155 million in the third quarter 2018 and $16 million in the third quarter 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Total restructuring charges for the nine months ended September 30, 2018 and 2017 were comprised of the following: 2018 2017 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, $83 $14 $97 $70 $21 $91 Restructuring costs accrued 103 — 103 89 — 89 Non-cash portion — — — — (7 ) (7 ) Cash paid out — — — 100 — 100 Balance as of September 30, $186 $14 $200 $59 $14 $73

Risk Management And Fair Valu_2

Risk Management And Fair Values (Tables)	9 Months Ended
	Sep. 30, 2018
Fair Values Of Derivative Instruments	The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $10 ($10) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $62 ($10) $52 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $24 ($11) $13 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $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 $4 ($3) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Entergy Wholesale Commodities The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 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 $30 million posted as of September 30, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes letters of credit in the amount of $5 million posted as of September 30, 2018 and $34 million in letters of credit held as of December 31, 2017.
Derivative Instruments Designated As Cash Flow Hedges On Consolidated Statements Of Income	The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2018 Electricity swaps and options ($51) Competitive businesses operating revenues ($11) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $23 (a) Before taxes of ($2) million and $8 million for the three months ended September 30, 2018 and 2017, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options ($40) Competitive businesses operating revenues ($38) 2017 Electricity swaps and options $136 Competitive businesses operating revenues $87 (a) Before taxes of ($8) million and $30 million for the nine months ended September 30, 2018 and 2017, respectively
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $31 Electricity swaps and options $— (c) Competitive business operating revenues ($2) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights $— Purchased power expense (b) $28 Electricity swaps and options ($2) (c) Competitive business operating revenues $— The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights $— Purchased power expense (b) $104 Electricity swaps and options $— (c) Competitive business operating revenues $— 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($20) Financial transmission rights $— Purchased power expense (b) $103 Electricity swaps and options $2 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps 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 are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items.
Assets and liabilities at fair value on a recurring basis	The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2018 and December 31, 2017 . 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. 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $923 $— $— $923 Decommissioning trust funds (a): Equity securities 1,569 — — 1,569 Debt securities 1,167 1,678 — 2,845 Common trusts (b) 3,030 Securitization recovery trust account 58 — — 58 Escrow accounts 401 — — 401 Gas hedge contracts 1 — — 1 Financial transmission rights — — 29 29 $4,119 $1,678 $29 $8,856 Liabilities: Power contracts $— $— $67 $67 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $725 $— $— $725 Decommissioning trust funds (a): Equity securities 526 — — 526 Debt securities 1,125 1,425 — 2,550 Common trusts (b) 4,136 Power contracts — — 5 5 Securitization recovery trust account 45 — — 45 Escrow accounts 406 — — 406 Financial transmission rights — — 21 21 $2,827 $1,425 $26 $8,414 Liabilities: Power contracts $— $— $70 $70 Gas hedge contracts 6 — — 6 $6 $— $70 $76 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018 and 2017 : 2018 2017 Power Contracts Financial transmission rights Power Contracts Financial transmission rights (In Millions) Balance as of July 1, ($25 ) $41 $38 $57 Total gains (losses) for the period (a) Included in earnings (4 ) — 2 — Included in other comprehensive income (51 ) — 43 — Included as a regulatory liability/asset — 19 — 8 Settlements 13 (31 ) (23 ) (28 ) Balance as of September 30, ($67 ) $29 $60 $37 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is $1.7 million for the three months ended September 30, 2018 and $0.4 million for the three months ended September 30, 2017. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018 and 2017 : 2018 2017 Power Contracts Financial transmission rights Power Contracts Financial transmission rights (In Millions) Balance as of January 1, ($65 ) $21 $5 $21 Total gains (losses) for the period (a) Included in earnings (5 ) (1 ) 6 1 Included in other comprehensive income (40 ) — 136 — Included as a regulatory liability/asset — 67 — 56 Issuances of financial transmission rights — 46 — 62 Settlements 43 (104 ) (87 ) (103 ) Balance as of September 30, ($67 ) $29 $60 $37 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is $1.1 million for the nine months ended September 30, 2018 and $1 million for the nine months ended September 30, 2017.
Fair Value Inputs Liabilities Quantitative Information	The following table sets forth a description of the types of transactions classified as Level 3 in the fair value hierarchy and significant unobservable inputs to each which cause that classification as of September 30, 2018 : Transaction Type Fair Value as of September 30, 2018 Significant Unobservable Inputs Range from Average % Effect on Fair Value (In Millions) (In Millions) Power contracts - electricity swaps ($67) 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 September 30, 2018 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $1.0 $— $1.0 Entergy Louisiana Natural gas swaps Prepayments and other $0.4 $— $0.4 Entergy Mississippi Financial transmission rights Prepayments and other $11.6 ($0.3) $11.3 Entergy Arkansas Financial transmission rights Prepayments and other $12.2 ($0.2) $12.0 Entergy Louisiana Financial transmission rights Prepayments and other $3.7 $— $3.7 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($1.6) $0.1 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas.
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.6) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.2 (b) Entergy Arkansas Financial transmission rights Purchased power expense $9.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.0 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.1) (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 $19.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $38.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $16.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $7.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $19.2 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps 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 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 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $208.7 $— $— $208.7 Decommissioning trust funds (a): Equity securities 2.2 — — 2.2 Debt securities 111.0 267.5 — 378.5 Common trusts (b) 616.2 Securitization recovery trust account 8.6 — — 8.6 Financial transmission rights — — 11.3 11.3 $330.5 $267.5 $11.3 $1,225.5 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Decommissioning trust funds (a): Equity securities $11.7 $— $— $11.7 Debt securities 115.8 232.4 — 348.2 Common trusts (b) 585.0 Securitization recovery trust account 3.7 — — 3.7 Escrow accounts 2.4 — — 2.4 Financial transmission rights — — 3.0 3.0 $133.6 $232.4 $3.0 $954.0
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, 2018 $10.5 $18.2 $4.4 $3.0 $4.7 Gains included as a regulatory liability/asset 10.9 7.6 4.7 1.1 (5.0 ) Settlements (10.1 ) (13.8 ) (5.4 ) (2.0 ) 0.4 Balance as of September 30, 2018 $11.3 $12.0 $3.7 $2.1 $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2017 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, 2017 $8.3 $28.3 $9.1 $5.2 $5.5 Gains included as a regulatory liability/asset 0.3 (0.1 ) 1.1 0.2 6.5 Settlements (4.2 ) (9.4 ) (4.7 ) (1.9 ) (7.0 ) Balance as of September 30, 2017 $4.4 $18.8 $5.5 $3.5 $5.0 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2018 $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 included as a regulatory liability/asset 16.6 39.0 20.1 6.7 (15.0 ) Settlements (20.1 ) (57.2 ) (23.0 ) (10.5 ) 5.6 Balance as of September 30, 2018 $11.3 $12.0 $3.7 $2.1 $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2017 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2017 $5.4 $8.5 $3.2 $1.1 $3.1 Issuances of financial transmission rights 8.9 31.0 9.6 5.0 7.1 Gains (losses) included as a regulatory liability/asset 9.4 18.2 9.0 5.1 14.0 Settlements (19.3 ) (38.9 ) (16.3 ) (7.7 ) (19.2 ) Balance as of September 30, 2017 $4.4 $18.8 $5.5 $3.5 $5.0
Entergy Louisiana [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2018 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $1.0 $— $1.0 Entergy Louisiana Natural gas swaps Prepayments and other $0.4 $— $0.4 Entergy Mississippi Financial transmission rights Prepayments and other $11.6 ($0.3) $11.3 Entergy Arkansas Financial transmission rights Prepayments and other $12.2 ($0.2) $12.0 Entergy Louisiana Financial transmission rights Prepayments and other $3.7 $— $3.7 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($1.6) $0.1 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas.
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.6) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.2 (b) Entergy Arkansas Financial transmission rights Purchased power expense $9.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.0 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.1) (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 $19.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $38.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $16.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $7.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $19.2 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps 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 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 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $213.2 $— $— $213.2 Decommissioning trust funds (a): Equity securities 12.9 — — 12.9 Debt securities 157.9 362.6 — 520.5 Common trusts (b) 861.8 Escrow accounts 288.1 — — 288.1 Securitization recovery trust account 10.0 — — 10.0 Gas hedge contracts 1.0 — — 1.0 Financial transmission rights — — 12.0 12.0 $683.1 $362.6 $12.0 $1,919.5 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $30.1 $— $— $30.1 Decommissioning trust funds (a): Equity securities 15.2 — — 15.2 Debt securities 143.3 350.5 — 493.8 Common trusts (b) 803.1 Escrow accounts 289.5 — — 289.5 Securitization recovery trust account 2.0 — — 2.0 Financial transmission rights — — 10.2 10.2 $480.1 $350.5 $10.2 $1,643.9 Liabilities: Gas hedge contracts $5.0 $— $— $5.0
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, 2018 $10.5 $18.2 $4.4 $3.0 $4.7 Gains included as a regulatory liability/asset 10.9 7.6 4.7 1.1 (5.0 ) Settlements (10.1 ) (13.8 ) (5.4 ) (2.0 ) 0.4 Balance as of September 30, 2018 $11.3 $12.0 $3.7 $2.1 $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2017 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, 2017 $8.3 $28.3 $9.1 $5.2 $5.5 Gains included as a regulatory liability/asset 0.3 (0.1 ) 1.1 0.2 6.5 Settlements (4.2 ) (9.4 ) (4.7 ) (1.9 ) (7.0 ) Balance as of September 30, 2017 $4.4 $18.8 $5.5 $3.5 $5.0 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2018 $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 included as a regulatory liability/asset 16.6 39.0 20.1 6.7 (15.0 ) Settlements (20.1 ) (57.2 ) (23.0 ) (10.5 ) 5.6 Balance as of September 30, 2018 $11.3 $12.0 $3.7 $2.1 $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2017 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2017 $5.4 $8.5 $3.2 $1.1 $3.1 Issuances of financial transmission rights 8.9 31.0 9.6 5.0 7.1 Gains (losses) included as a regulatory liability/asset 9.4 18.2 9.0 5.1 14.0 Settlements (19.3 ) (38.9 ) (16.3 ) (7.7 ) (19.2 ) Balance as of September 30, 2017 $4.4 $18.8 $5.5 $3.5 $5.0
Entergy Mississippi [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2018 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $1.0 $— $1.0 Entergy Louisiana Natural gas swaps Prepayments and other $0.4 $— $0.4 Entergy Mississippi Financial transmission rights Prepayments and other $11.6 ($0.3) $11.3 Entergy Arkansas Financial transmission rights Prepayments and other $12.2 ($0.2) $12.0 Entergy Louisiana Financial transmission rights Prepayments and other $3.7 $— $3.7 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($1.6) $0.1 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas.
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.6) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.2 (b) Entergy Arkansas Financial transmission rights Purchased power expense $9.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.0 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.1) (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 $19.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $38.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $16.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $7.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $19.2 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps 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 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 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Escrow accounts $32.3 $— $— $32.3 Gas hedge contracts 0.4 — — 0.4 Financial transmission rights — — 3.7 3.7 $32.7 $— $3.7 $36.4 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $4.5 $— $— $4.5 Escrow accounts 32.0 — — 32.0 Financial transmission rights — — 2.1 2.1 $36.5 $— $2.1 $38.6 Liabilities: Gas hedge contracts $1.2 $— $— $1.2
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, 2018 $10.5 $18.2 $4.4 $3.0 $4.7 Gains included as a regulatory liability/asset 10.9 7.6 4.7 1.1 (5.0 ) Settlements (10.1 ) (13.8 ) (5.4 ) (2.0 ) 0.4 Balance as of September 30, 2018 $11.3 $12.0 $3.7 $2.1 $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2017 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, 2017 $8.3 $28.3 $9.1 $5.2 $5.5 Gains included as a regulatory liability/asset 0.3 (0.1 ) 1.1 0.2 6.5 Settlements (4.2 ) (9.4 ) (4.7 ) (1.9 ) (7.0 ) Balance as of September 30, 2017 $4.4 $18.8 $5.5 $3.5 $5.0 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2018 $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 included as a regulatory liability/asset 16.6 39.0 20.1 6.7 (15.0 ) Settlements (20.1 ) (57.2 ) (23.0 ) (10.5 ) 5.6 Balance as of September 30, 2018 $11.3 $12.0 $3.7 $2.1 $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2017 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2017 $5.4 $8.5 $3.2 $1.1 $3.1 Issuances of financial transmission rights 8.9 31.0 9.6 5.0 7.1 Gains (losses) included as a regulatory liability/asset 9.4 18.2 9.0 5.1 14.0 Settlements (19.3 ) (38.9 ) (16.3 ) (7.7 ) (19.2 ) Balance as of September 30, 2017 $4.4 $18.8 $5.5 $3.5 $5.0
Entergy New Orleans [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2018 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $1.0 $— $1.0 Entergy Louisiana Natural gas swaps Prepayments and other $0.4 $— $0.4 Entergy Mississippi Financial transmission rights Prepayments and other $11.6 ($0.3) $11.3 Entergy Arkansas Financial transmission rights Prepayments and other $12.2 ($0.2) $12.0 Entergy Louisiana Financial transmission rights Prepayments and other $3.7 $— $3.7 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($1.6) $0.1 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas.
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.6) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.2 (b) Entergy Arkansas Financial transmission rights Purchased power expense $9.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.0 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.1) (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 $19.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $38.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $16.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $7.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $19.2 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps 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 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 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $32.9 $— $— $32.9 Securitization recovery trust account 5.6 — — 5.6 Escrow accounts 80.4 — — 80.4 Financial transmission rights — — 2.1 2.1 $118.9 $— $2.1 $121.0 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $32.7 $— $— $32.7 Securitization recovery trust account 1.5 — — 1.5 Escrow accounts 81.9 — — 81.9 Financial transmission rights — — 2.2 2.2 $116.1 $— $2.2 $118.3 Liabilities: Gas hedge contracts $0.2 $— $— $0.2
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, 2018 $10.5 $18.2 $4.4 $3.0 $4.7 Gains included as a regulatory liability/asset 10.9 7.6 4.7 1.1 (5.0 ) Settlements (10.1 ) (13.8 ) (5.4 ) (2.0 ) 0.4 Balance as of September 30, 2018 $11.3 $12.0 $3.7 $2.1 $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2017 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, 2017 $8.3 $28.3 $9.1 $5.2 $5.5 Gains included as a regulatory liability/asset 0.3 (0.1 ) 1.1 0.2 6.5 Settlements (4.2 ) (9.4 ) (4.7 ) (1.9 ) (7.0 ) Balance as of September 30, 2017 $4.4 $18.8 $5.5 $3.5 $5.0 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2018 $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 included as a regulatory liability/asset 16.6 39.0 20.1 6.7 (15.0 ) Settlements (20.1 ) (57.2 ) (23.0 ) (10.5 ) 5.6 Balance as of September 30, 2018 $11.3 $12.0 $3.7 $2.1 $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2017 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2017 $5.4 $8.5 $3.2 $1.1 $3.1 Issuances of financial transmission rights 8.9 31.0 9.6 5.0 7.1 Gains (losses) included as a regulatory liability/asset 9.4 18.2 9.0 5.1 14.0 Settlements (19.3 ) (38.9 ) (16.3 ) (7.7 ) (19.2 ) Balance as of September 30, 2017 $4.4 $18.8 $5.5 $3.5 $5.0
Entergy Texas [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2018 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 Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $1.0 $— $1.0 Entergy Louisiana Natural gas swaps Prepayments and other $0.4 $— $0.4 Entergy Mississippi Financial transmission rights Prepayments and other $11.6 ($0.3) $11.3 Entergy Arkansas Financial transmission rights Prepayments and other $12.2 ($0.2) $12.0 Entergy Louisiana Financial transmission rights Prepayments and other $3.7 $— $3.7 Entergy Mississippi Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.7 ($1.6) $0.1 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $1 million for Entergy Arkansas, $0.2 million for Entergy Mississippi, and $3.6 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas.
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy Mississippi Financial transmission rights Purchased power expense $10.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $13.8 (b) Entergy Louisiana Financial transmission rights Purchased power expense $5.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($0.4) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.6) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.2 (b) Entergy Arkansas Financial transmission rights Purchased power expense $9.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.0 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $4.2 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.9 (a) Entergy Mississippi Financial transmission rights Purchased power expense $20.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $57.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $23.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $10.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($5.6) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.1) (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 $19.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $38.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $16.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $7.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $19.2 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps 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 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 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $19.0 $— $— $19.0 Securitization recovery trust account 33.7 — — 33.7 Financial transmission rights — — 0.1 0.1 $52.7 $— $0.1 $52.8 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $115.5 $— $— $115.5 Securitization recovery trust account 37.7 — — 37.7 Financial transmission rights — — 3.4 3.4 $153.2 $— $3.4 $156.6
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, 2018 $10.5 $18.2 $4.4 $3.0 $4.7 Gains included as a regulatory liability/asset 10.9 7.6 4.7 1.1 (5.0 ) Settlements (10.1 ) (13.8 ) (5.4 ) (2.0 ) 0.4 Balance as of September 30, 2018 $11.3 $12.0 $3.7 $2.1 $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2017 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, 2017 $8.3 $28.3 $9.1 $5.2 $5.5 Gains included as a regulatory liability/asset 0.3 (0.1 ) 1.1 0.2 6.5 Settlements (4.2 ) (9.4 ) (4.7 ) (1.9 ) (7.0 ) Balance as of September 30, 2017 $4.4 $18.8 $5.5 $3.5 $5.0 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2018 $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 included as a regulatory liability/asset 16.6 39.0 20.1 6.7 (15.0 ) Settlements (20.1 ) (57.2 ) (23.0 ) (10.5 ) 5.6 Balance as of September 30, 2018 $11.3 $12.0 $3.7 $2.1 $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2017 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2017 $5.4 $8.5 $3.2 $1.1 $3.1 Issuances of financial transmission rights 8.9 31.0 9.6 5.0 7.1 Gains (losses) included as a regulatory liability/asset 9.4 18.2 9.0 5.1 14.0 Settlements (19.3 ) (38.9 ) (16.3 ) (7.7 ) (19.2 ) Balance as of September 30, 2017 $4.4 $18.8 $5.5 $3.5 $5.0
System Energy [Member]
Assets and liabilities at fair value on a recurring basis	System Energy 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $254.4 $— $— $254.4 Decommissioning trust funds (a): Equity securities 7.4 — — 7.4 Debt securities 211.1 148.1 — 359.2 Common trusts (b) 585.8 $472.9 $148.1 $— $1,206.8 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $287.1 $— $— $287.1 Decommissioning trust funds (a): Equity securities 3.1 — — 3.1 Debt securities 187.2 143.3 — 330.5 Common trusts (b) 572.1 $477.4 $143.3 $— $1,192.8

Decommissioning Trust Funds (Ta

Decommissioning Trust Funds (Tables)	9 Months Ended
	Sep. 30, 2018
Securities Held	The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities (a) $2,448 $10 $51 2017 Equity Securities $4,662 $2,131 $1 Debt Securities 2,550 44 16 Total $7,212 $2,175 $17 (a) Debt securities presented herein do not include the $397 million of debt securities held in the wholly-owned registered investment company, 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 investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1,691 $33 More than 12 months 357 18 Total $2,048 $51 The fair value and gross unrealized losses of available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8 $1 $1,099 $7 More than 12 months — — 265 9 Total $8 $1 $1,364 $16
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $119 $74 1 year - 5 years 934 902 5 years - 10 years 628 812 10 years - 15 years 108 147 15 years - 20 years 92 100 20 years+ 567 515 Total $2,448 $2,550
Entergy Arkansas [Member]
Securities Held	The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities $378.5 $0.2 $10.9 2017 Equity Securities $596.7 $354.9 $— Debt Securities 348.2 2.1 3.0 Total $944.9 $357.0 $3.0
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 investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $259.7 $6.8 More than 12 months 78.2 4.1 Total $337.9 $10.9 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $168.0 $1.2 More than 12 months — — 41.4 1.8 Total $— $— $209.4 $3.0
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $40.8 $13.0 1 year - 5 years 174.4 123.4 5 years - 10 years 115.6 180.6 10 years - 15 years 10.6 4.8 15 years - 20 years 5.8 3.4 20 years+ 31.3 23.0 Total $378.5 $348.2
Entergy Louisiana [Member]
Securities Held	The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities $520.5 $2.0 $9.3 2017 Equity Securities $818.3 $461.2 $— Debt Securities 493.8 10.9 3.6 Total $1,312.1 $472.1 $3.6
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 investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $355.6 $5.8 More than 12 months 74.0 3.5 Total $429.6 $9.3 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $135.3 $1.1 More than 12 months — — 84.4 2.5 Total $— $— $219.7 $3.6
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $22.4 $23.2 1 year - 5 years 122.0 122.8 5 years - 10 years 117.9 109.3 10 years - 15 years 37.7 52.7 15 years - 20 years 41.3 50.7 20 years+ 179.2 135.1 Total $520.5 $493.8
System Energy [Member]
Securities Held	The available-for-sale securities held as of September 30, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities $359.2 $0.9 $7.1 2017 Equity Securities $575.2 $308.6 $— Debt Securities 330.5 4.2 1.2 Total $905.7 $312.8 $1.2
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 investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $267.6 $5.2 More than 12 months 34.3 1.9 Total $301.9 $7.1 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $196.9 $1.0 More than 12 months — — 10.4 0.2 Total $— $— $207.3 $1.2
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $2.2 $4.1 1 year - 5 years 195.4 173.0 5 years - 10 years 78.2 78.5 10 years - 15 years 5.6 1.0 15 years - 20 years 11.0 6.9 20 years+ 66.8 67.0 Total $359.2 $330.5

Revenue Recognition Revenue Rec

Revenue Recognition Revenue Recognition (Tables)	9 Months Ended
	Sep. 30, 2018
Disaggregation of Revenue [Table Text Block]	Entergy’s total revenues for the three and nine months ended September 30, 2018 were as follows: 2018 Three Months Ended Nine Months Ended (In Thousands) Utility: Residential $1,138,744 $2,799,539 Commercial 693,760 1,871,380 Industrial 682,823 1,904,828 Governmental 60,647 173,949 Total billed retail 2,575,974 6,749,696 Sales for resale (a) 76,247 214,984 Other electric revenues (b) 42,847 289,668 Non-customer revenues (c) 2,819 22,026 Total electric revenues 2,697,887 7,276,374 Natural gas 26,352 112,990 Entergy Wholesale Commodities: Competitive businesses sales (a) 407,763 1,148,460 Non-customer revenues (c) (27,683 ) (40,854 ) Total competitive businesses 380,080 1,107,606 Total operating revenues $3,104,319 $8,496,970
Entergy Arkansas [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657
Entergy Louisiana [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657
Entergy Mississippi [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657
Entergy New Orleans [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657
Entergy Texas [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $250,081 $408,680 $170,258 $86,014 $223,711 Commercial 119,950 272,985 126,987 62,428 111,409 Industrial 126,079 393,884 44,383 9,655 108,823 Governmental 4,445 17,566 11,488 20,364 6,785 Total billed retail 500,555 1,093,115 353,116 178,461 450,728 Sales for resale (a) 60,338 71,634 7,876 4,863 23,290 Other electric revenues (b) 4,446 34,220 4,079 (1,107 ) 2,735 Non-customer revenues (c) 3,060 (2,691 ) 2,663 1,947 478 Total electric revenues 568,399 1,196,278 367,734 184,164 477,231 Natural gas — 10,334 — 16,018 — Total operating revenues $568,399 $1,206,612 $367,734 $200,182 $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $644,735 $972,113 $451,331 $208,821 $522,539 Commercial 334,325 719,652 354,799 171,224 291,380 Industrial 335,529 1,114,898 133,012 26,493 294,896 Governmental 12,859 51,581 33,788 56,503 19,218 Total billed retail 1,327,448 2,858,244 972,930 463,041 1,128,033 Sales for resale (a) 179,637 272,690 21,645 24,390 71,828 Other electric revenues (b) 98,571 124,749 35,055 7,404 28,468 Non-customer revenues (c) 8,372 7,390 7,536 4,749 1,328 Total electric revenues 1,614,028 3,263,073 1,037,166 499,584 1,229,657 Natural gas — 45,671 — 67,319 — Total operating revenues $1,614,028 $3,308,744 $1,037,166 $566,903 $1,229,657

Commitments and Contingencies C

Commitments and Contingencies Commitments and Contingencies (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2018	Sep. 30, 2017
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		$ 0	$ 25,493
Entergy Nuclear Generation Company [Member]
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	$ 62,000

Rate And Regulatory Matters (Na

Rate And Regulatory Matters (Narrative) (Details)	1 Months Ended													3 Months Ended	4 Months Ended	9 Months Ended		12 Months Ended		72 Months Ended
	Oct. 31, 2018USD ($)	Sep. 30, 2018USD ($)	Aug. 31, 2018USD ($)	Jul. 31, 2018USD ($)	Jun. 30, 2018USD ($)	May 31, 2018USD ($)	Apr. 30, 2018USD ($)	Mar. 31, 2018USD ($)$ / kWh	Jan. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Aug. 31, 2017	Jan. 31, 2017	Jul. 31, 2015USD ($)	Sep. 30, 2018USD ($)	Oct. 31, 2016USD ($)	Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2024USD ($)
Regulatory Assets [Line Items]
Impairment of Long-Lived Assets Held-for-use																$ 210,263,000	$ 241,838,000
Deferred Fuel Cost		$ 61,309,000								$ 95,746,000				$ 61,309,000		61,309,000			$ 95,746,000
Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Reduction in Revenue Requirement				$ 3,500,000
Earned return on common equity							10.79%		9.06%
Public Utilities, proposed customer credits							$ 700,000
Proposed prospective reduction in the gas infrastructure rider							$ 200,000
Authorized return on common equity							9.95%				9.95%
Earned Return on Common Equity Resulting From Revenue-Neutral Realignments to Other Recovery Mechanisms					8.16%
Earnings bandwidth basis points											16000.00%
Reduced earnings bandwidth basis points											8000.00%
Public Utilities, Requested Increase in Revenue Requirement									$ 100,000
Monthly increase in regulatory liability related to Tax Act																9,100,000
Regulatory liability related to Tax Act		67,000,000												67,000,000		67,000,000
Target earned return on common equity							9.80%
Common equity basis point bandwidth							$ 60
Cap on potential revenue increase for 2018 rate case evaluation period							35,000,000
Cap on potential revenue increase for 2018 and 2019 rate case evaluation periods							70,000,000
Requirement for excess transmission project costs eligible for costs recovery mechanism							$ 100,000,000
Earned Return on Common Equity Excluding Realignments					9.88%
Rate Increase Included in Formula Rate Plan					$ 4,800,000
Formula rate plan increase excluding Tax Cuts and Jobs Act Credits					98,000,000
Formula rate plan revenue decrease			$ 17,600,000
Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Authorized Storm Damage Reserve Balance		15,000,000			15,000,000									15,000,000		15,000,000
Balance At Which Storm Damage Accrual Will Return To Current Level																10,000,000
Deferred Fuel Cost		22,618,000								32,444,000				22,618,000		22,618,000			32,444,000
System Agreement Bandwidth Remedy Payments																16,000,000
Monthly storm damage provision			$ 0													1,750,000
Offset of Unprotected Excess ADIT Against Net Utility Plant Approved in Stipulation					127,200,000
Offset of Unprotected Excess ADIT Against Other Regulatory Assets Approved in Stipulation					2,200,000
Return of excess ADIT through customer bill credits														25,800,000
Return of unprotected excess ADIT through sale of fuel oil inventory														5,800,000
Proposed customer credits due to internal restructuring								$ 27,000,000
Approved customer credits due to internal restructuring		$ 27,000,000
Preferred Stock, Redemption Amount								21,200,000
Entergy Mississippi [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
MPSC approved customer credits due to internal restructuring																				$ 4,500,000
Entergy New Orleans [Member]
Regulatory Assets [Line Items]
System Agreement Bandwidth Remedy Payments																5,000,000
Benefit to electric customers related to reduction in income tax expense under Tax Act								8,200,000
Benefit to gas customers related to reduction in income tax expense under Tax Act								$ 1,300,000
Allocation of benefits resulting from Tax Cuts and Jobs Act to Energy Smart Programs					13,500,000
Incremental costs related to one year acceleration of implementation of advanced metering infrastructure					$ 4,400,000
Estimated implementation costs for advanced metering infrastructure (AMI)																79,400,000
Entergy New Orleans [Member] | Electricity [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage		10.50%
Proposed rate reduction in revised filing		$ 20,300,000
Revised Increase In Rate Base Request		135,200,000
Portion of base rate increase associated with moving costs from rider into rates		131,500,000
Proposed surcharge to recover advanced metering infrastructure costs		7,100,000
Rate reduction due to decrease in projected fuel and energy efficiency riders		$ 31,100,000
Return on equity including performance adder provision		10.75%
Entergy New Orleans [Member] | Natural Gas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage		10.75%
Proposed rate reduction in revised filing		$ 142,000
Entergy New Orleans [Member] | Minimum [Member]
Regulatory Assets [Line Items]
Earnings bandwidth basis points				5000.00%
Entergy New Orleans [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Earnings bandwidth basis points				5000.00%
Entergy Texas [Member]
Regulatory Assets [Line Items]
System Agreement Bandwidth Remedy Payments													$ 10,900,000		$ 10,900,000	6,000,000
Refund for fuel cost recovery										30,500,000
Public Utilities, Requested Increase in Revenue Requirement						$ 118,000,000
Public Utilities, Requested Rate Increase (Decrease), Amount						166,000,000
Portion of requested increase in base rates associated with moving costs						$ 48,000,000
Entergy Texas [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 53,200,000
Refund due customers resulting from lower federal income tax rate	25,000,000
Capitalized skylining tree hazard costs	6,000,000
Refund to customers of protected excess accumulated deferred taxes	242,500,000
Return of excess ADIT through customer bill credits	185,200,000
Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Payments due Utility Operating Companies Related to Opportunity Sales Proceedings		68,000,000												68,000,000		68,000,000
Interest owed to Utility operating companies on Opportunity Sales proceeding		64,000,000												64,000,000		64,000,000
Total payable including interest due Utiilty operating companies resulting from Opportunity Sales proceeding		132,000,000												132,000,000		132,000,000
Regulatory Asset Recorded to Represent Estimate of Recoverable Retail Portion of Costs		114,000,000												114,000,000		114,000,000
Deferred Fuel Cost		$ 38,691,000								$ 63,302,000				38,691,000		$ 38,691,000			63,302,000
Rate At Which Electricity Sold To Retail Customers | $ / kWh								0.01547
Increase in Rate At Which Electricity Sold To Retail Customers | $ / kWh								0.01882
Projected Revenue Deficiency																			$ 95,600,000
Projected Increase in Revenue Requirement				$ 169,000,000
Annual revenue constraint per rate class percentage				400.00%
Reduced proposed increase in revenue requirement to comply with annual revenue constraint				$ 65,400,000
Entergy Arkansas [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Portion of Energy Cost Recovery Rider Redetermination Subject to Possible Refund to Customers	$ 45,700,000
Projected Revenue Deficiency																		$ 73,400,000
Proposed customer credits due to internal restructuring																				$ 39,600,000
System Energy [Member]
Regulatory Assets [Line Items]
Earned return on common equity																10.94%
Percent Interest in Grand Gulf						11.50%										90.00%
Reduction of previously recorded deprecation expense														$ 26,000,000
System Energy [Member] | Minimum [Member]
Regulatory Assets [Line Items]
Earned return on common equity												8.37%
System Energy [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Earned return on common equity												8.67%

Rate And Regulatory Matters Sys

Rate And Regulatory Matters System Agreement Cost Equalization Payments (Receipts) Among Utility Operating Companies (Details) - USD ($) $ in Millions	1 Months Ended	4 Months Ended	9 Months Ended
	Jul. 31, 2015	Oct. 31, 2016	Sep. 30, 2018
Entergy Arkansas [Member]
System Agreement Bandwidth Remedy Receipts			$ (4)
Entergy Louisiana [Member]
System Agreement Bandwidth Remedy Receipts			(23)
Entergy Mississippi [Member]
System Agreement Bandwidth Remedy Payments			16
Entergy New Orleans [Member]
System Agreement Bandwidth Remedy Payments			5
Entergy Texas [Member]
System Agreement Bandwidth Remedy Payments	$ 10.9	$ 10.9	$ 6

Rate And Regulatory Matters Rou

Rate And Regulatory Matters Rough Production Cost Equalization Payments (Receipts) Among Utility Operating Companies (Details) $ in Millions	9 Months Ended
	Sep. 30, 2018USD ($)
Entergy Arkansas [Member]
Rough production cost equalization payments	$ 3
Entergy Louisiana [Member]
Rough production cost equalization payments	3
Entergy Mississippi [Member]
Rough production cost equalization receipts	(1)
Entergy New Orleans [Member]
Rough production cost equalization payments	1
Entergy Texas [Member]
Rough production cost equalization receipts	$ (5)

Equity (Narrative) (Details)

Equity (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands		Oct. 26, 2018	Jun. 30, 2018	Sep. 30, 2018	Mar. 31, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Jan. 01, 2018
Equity [Abstract]
Stock Options Excluded From Diluted Common Shares Outstanding Calculation				1,100,000		2,500,000	1,100,000	3,300,000
Forward Contract Indexed to Issuer's Equity, Indexed Shares			15,300,000
Forward Contract Indexed to Issuer's Equity, Shares							1,400,000
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share			$ 74.45
Shares, Issued				613,662			613,662
Common stock dividend (in dollars per share)				$ 0.89		$ 0.87	$ 2.67	$ 2.61
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax									$ 632,617
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	[1]								$ 56,360
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects					$ 15,500		$ 15,505
Tax Cuts and Jobs Act, Portion Reclassified from AOCI to Retained Earnings					32,000
Tax Cuts and Jobs Act, Portion Reclassified from AOCI to Regulatory Liability for Income Taxes					$ 16,500
Subsequent Event [Member]
Equity [Abstract]
Common stock dividend (in dollars per share)		$ 0.91
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2018 and 2017 include $10.3 million and $10.3 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Equity (Schedule Of Earnings Pe

Equity (Schedule Of Earnings Per Share, Basic And Diluted) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Incremental Weighted Average Shares Attributable to Dilutive Effect [Abstract]
Stock options, Shares	400,000	200,000	300,000	200,000
Stock options $/share	$ 0	$ 0	$ 0	$ 0
Restricted stock, Shares	800,000	700,000	700,000	500,000
Restricted stock $/share	$ (0.01)	$ (0.01)	$ 0	$ 0
Incremental Common Shares Attributable to Dilutive Effect of Equity Forward Agreements	1,500,000	0	900,000	0
Average Dilutive Effect Of Equity Forwards	$ (0.02)	$ 0	$ (0.03)	$ 0
Basic earnings per share
Net income (loss) attributable to Entergy Corporation, Income	$ 536,379	$ 398,198	$ 914,560	$ 890,726
Net Income Attributable to Entergy Corporation, Shares	181,002,303	179,563,819	180,845,440	179,458,914
Net Income Attributable to Entergy Corporation, $/share	$ 2.96	$ 2.22	$ 5.06	$ 4.96
Diluted earnings per share, Shares	183,664,583	180,464,069	182,692,325	180,163,074
Diluted earnings per share $/share	$ 2.92	$ 2.21	$ 5.01	$ 4.94

Equity (Accumulated Other Compr

Equity (Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands		3 Months Ended			9 Months Ended
		Sep. 30, 2018	Mar. 31, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Jun. 30, 2018	Jan. 01, 2018	Dec. 31, 2017	Jun. 30, 2017	Dec. 31, 2016
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax								$ (632,617)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss		$ (632,126)		$ 111,678	$ (632,126)	$ 111,678	$ (613,642)		$ (23,531)	$ 52,773	$ (34,971)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax		(47,574)		63,514	(82,774)	197,174
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		29,090		(4,609)	91,291	(50,525)
Other comprehensive income (loss)		(18,484)		58,905	8,517	146,649
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect	[1]				(16,538)
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects			$ 15,500		15,505
Accumulated Foreign Currency Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss				0		0					748
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax						(748)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax						0
Other comprehensive income (loss)						(748)
Accumulated Net Investment Gain (Loss) Attributable to Parent [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax								(632,617)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss		(10,587)		512,652	(10,587)	512,652	(8,842)		545,045	479,257	429,734
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax		(7,173)		35,630	(50,958)	109,372
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		5,428		(2,235)	13,716	(26,454)
Other comprehensive income (loss)		(1,745)		33,395	(37,242)	82,918
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects					114,227
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax								0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss		(574,661)		(437,601)	(574,661)	(437,601)	(589,926)		(531,099)	(449,898)	(469,446)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax		0		0	0	0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		15,265		12,297	47,404	31,845
Other comprehensive income (loss)		15,265		12,297	47,404	31,845
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]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax								0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss		(46,878)		36,627	(46,878)	36,627	(14,874)		(37,477)	23,414	3,993
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax		(40,401)		27,884	(31,816)	88,550
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		8,397		(14,671)	30,171	(55,916)
Other comprehensive income (loss)		(32,004)		13,213	(1,645)	32,634
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		(57,951)			(57,951)				(46,400)
Other comprehensive income (loss)		(500)		(370)	(1,502)	(1,050)
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect					(3,787)
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss		(57,951)		(49,492)	(57,951)	(49,492)	$ (57,451)		$ (46,400)	$ (49,122)	$ (48,442)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		(500)		(370)	(1,502)	(1,050)
Other comprehensive income (loss)		$ (500)		$ (370)	(1,502)	(1,050)
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects					$ (10,049)	$ 0
Restatement Adjustment [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss								(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								(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								(531,099)
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								$ (37,477)
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2018 and 2017 include $10.3 million and $10.3 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Equity (Reclassification out of

Equity (Reclassification out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018		Sep. 30, 2017
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 3,104,319	$ 3,243,628	$ 8,496,970		$ 8,450,636
Other Nonoperating Income (Expense)	(43,591)	(31,335)	(123,439)		(78,726)
Income taxes (benefits)	283,006	(241,795)	519,937		87,555
Consolidated net income	539,818	401,644	924,877	[1]	901,064	[1]
Competitive Businesses [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	380,080	423,245	1,107,606		1,293,867
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Consolidated net income	(29,090)	4,609	(91,291)		50,525
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]
Consolidated net income	(5,428)	2,235	(13,716)		26,454
Parent Company [Member] | 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)	(63)	(185)	(278)		(654)
INCOME (LOSS) BEFORE INCOME TAXES	(10,629)	22,571	(38,191)		86,024
Income taxes (benefits)	2,232	(7,900)	8,020		(30,108)
Consolidated net income	(8,397)	14,671	(30,171)		55,916
Parent Company [Member] | 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	(10,566)	22,756	(37,913)		86,678
Parent Company [Member] | 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)	(8,589)	4,382	(21,703)		51,871
Income taxes (benefits)	3,161	(2,147)	7,987		(25,417)
Parent Company [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	5,425	6,565	16,278		19,691
Amortization of loss	(24,740)	(21,480)	(74,503)		(64,605)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	(76)	(4,200)	(2,098)		(5,965)
INCOME (LOSS) BEFORE INCOME TAXES	(19,391)	(19,115)	(60,323)		(50,879)
Income taxes (benefits)	4,126	6,818	12,919		19,034
Consolidated net income	(15,265)	(12,297)	(47,404)		(31,845)
Entergy Louisiana [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,206,612	1,290,494	3,308,744		3,254,711
Other Nonoperating Income (Expense)	(25,782)	(11,542)	(56,217)		(29,573)
Income taxes (benefits)	(2,944)	(94,098)	30,430		(193,759)
Consolidated net income	218,308	186,284	514,260		405,141
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	1,934	1,934	5,802		5,802
Amortization of loss	(1,257)	(1,332)	(3,770)		(3,996)
INCOME (LOSS) BEFORE INCOME TAXES	677	602	2,032		1,806
Income taxes (benefits)	(177)	(232)	(530)		(756)
Consolidated net income	$ 500	$ 370	$ 1,502		$ 1,050
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2018 and 2017 include $10.3 million and $10.3 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Revolving Credit Facilities, _3

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended					9 Months Ended
	Oct. 31, 2018	Sep. 30, 2018	Aug. 31, 2018	May 31, 2018	Mar. 31, 2018	Sep. 30, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Short-term borrowings		$ 1,946,677				$ 1,946,677	$ 1,578,308
Amount of Facility		3,500,000				3,500,000
Amount of total borrowing capacity against which fronting commitments exist		20,000				$ 20,000
Line of credit facility, commitment fee percentage						0.225%
Amount Drawn/ Outstanding		630,000				$ 630,000
Commercial Paper program limit		2,000,000				2,000,000
Commercial Paper Amount Outstanding		$ 1,947,000				$ 1,947,000
Commercial Paper Program [Member]
Debt Instrument [Line Items]
Debt, weighted average interest rate		2.42%				2.42%
Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Interest Rate During Period						3.46%
Entergy Arkansas [Member]
Debt Instrument [Line Items]
Short-term borrowings		$ 0				$ 0	49,974
Authorized Short Term Borrowings		250,000				250,000
Amount of total borrowing capacity against which fronting commitments exist		5,000				5,000
Letters of Credit Outstanding, Amount		1,000				1,000	200
Entergy Arkansas [Member] | Mortgage Bonds Four Point Zero Percent Series Due June 2028 [Member]
Debt Instrument [Line Items]
Issuance Of Debt				$ 250,000
Debt instrument, interest rate, stated percentage				4.00%
Entergy Arkansas [Member] | Preferred Stock 4.72% Series [Member]
Debt Instrument [Line Items]
Redemption of debt instrument				$ 9,350
Debt instrument, interest rate, stated percentage				4.72%
Entergy Arkansas [Member] | Preferred Stock 4.32% Series [Member]
Debt Instrument [Line Items]
Redemption of debt instrument				$ 7,000
Debt instrument, interest rate, stated percentage				4.32%
Entergy Arkansas [Member] | Preferred Stock 4.56% Series [Member]
Debt Instrument [Line Items]
Redemption of debt instrument				$ 15,000
Debt instrument, interest rate, stated percentage				4.56%
Entergy Louisiana [Member]
Debt Instrument [Line Items]
Short-term borrowings		0				0	43,540
Authorized Short Term Borrowings		450,000				450,000
Amount of total borrowing capacity against which fronting commitments exist		15,000				15,000
Entergy Louisiana [Member] | Mortgage Bonds, Four Point Zero Zero Percent due March Twenty Thirty Three [Member]
Debt Instrument [Line Items]
Issuance Of Debt					$ 750,000
Debt instrument, interest rate, stated percentage					4.00%
Entergy Louisiana [Member] | Mortgage Bonds Six Point Zero Percent Series Due May Twenty Eighteen [Member]
Debt Instrument [Line Items]
Redemption of debt instrument				$ 375,000
Debt instrument, interest rate, stated percentage				6.00%
Entergy Louisiana [Member] | Mortgage Bonds, 4.20% Series Due September 2048 [Domain]
Debt Instrument [Line Items]
Issuance Of Debt			$ 600,000
Debt instrument, interest rate, stated percentage			4.20%
Entergy Louisiana [Member] | Mortgage Bonds, 6.5% Series Due September 2018 [Domain]
Debt Instrument [Line Items]
Redemption of debt instrument			$ 300,000
Debt instrument, interest rate, stated percentage			6.50%
Entergy Mississippi [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		175,000				175,000
Letters of Credit Outstanding, Amount		200				200	100
Entergy Texas [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		200,000				200,000
Amount of total borrowing capacity against which fronting commitments exist		30,000				30,000
Letters of Credit Outstanding, Amount		3,600				3,600	50
System Energy [Member]
Debt Instrument [Line Items]
Short-term borrowings		0				0	$ 17,830
Authorized Short Term Borrowings		200,000				200,000
Entergy Nuclear Vermont Yankee [Member]
Debt Instrument [Line Items]
Amount of Facility		145,000				$ 145,000
Line of credit facility, commitment fee percentage						0.20%
Amount Drawn/ Outstanding		132,000				$ 132,000
Line of Credit Facility, Interest Rate During Period						3.37%
Entergy New Orleans [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		150,000				$ 150,000
Amount of total borrowing capacity against which fronting commitments exist		10,000				$ 10,000
Entergy New Orleans [Member] | Mortgage Bonds, 4.51% Series Due September 2033 [Domain]
Debt Instrument [Line Items]
Issuance Of Debt		$ 60,000
Debt instrument, interest rate, stated percentage		4.51%				4.51%
System Energy VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		$ 37,700				$ 37,700
Line of Credit Facility, Interest Rate During Period						3.18%
Line of credit facility commitment fee as a percentage of undrawn commitment amount						0.10%
System Energy VIE [Member] | Three Point Seven Eight Percent Series I Notes Due October Two Thousand Eighteen [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		3.78%				3.78%
System Energy VIE [Member] | Three Point Four Two Percent Series J Notes Due April Two Thousand Twenty One [Member]
Debt Instrument [Line Items]
Issuance Of Debt					$ 100,000
Debt instrument, interest rate, stated percentage		3.42%			3.42%	3.42%
Entergy Arkansas VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		$ 70,400				$ 70,400
Line of Credit Facility, Interest Rate During Period						3.18%
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		$ 30,500				$ 30,500
Line of Credit Facility, Interest Rate During Period						3.18%
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		$ 34,500				$ 34,500
Line of Credit Facility, Interest Rate During Period						3.18%
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						0.275%
Consolidated debt ratio		0.65				0.65
Maximum [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65				0.65
Consolidated debt ratio of total capitalization						70.00%
Maximum [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65				0.65
Consolidated debt ratio of total capitalization						70.00%
Maximum [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65				0.65
Maximum [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65				0.65
Maximum [Member] | System Energy [Member]
Debt Instrument [Line Items]
Consolidated debt ratio of total capitalization						70.00%
Maximum [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65				0.65
Minimum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment fee percentage						0.075%
Credit Facility Of Three Hundred Fifty Million [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Amount of Facility		$ 350,000			$ 350,000	$ 350,000
Letters of Credit Outstanding, Amount		0				0
Amount Drawn/ Outstanding		0				$ 0
Line of Credit Facility, Interest Rate During Period						3.49%
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Amount of Facility		150,000				$ 150,000
Letters of Credit Outstanding, Amount		0				0
Amount Drawn/ Outstanding		0				$ 0
Line of Credit Facility, Interest Rate During Period						3.49%
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Amount of Facility		150,000				$ 150,000
Letters of Credit Outstanding, Amount		1,300				1,300
Amount Drawn/ Outstanding		$ 0				$ 0
Line of Credit Facility, Interest Rate During Period						3.74%
Subsequent Event [Member] | System Energy VIE [Member] | 3.78% Series I Notes Due October 2018 [Domain]
Debt Instrument [Line Items]
Redemption of debt instrument	$ 85,000
Debt instrument, interest rate, stated percentage	3.78%

Revolving Credit Facilities, _4

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Summary Of The Borrowings Outstanding And Capacity Available Under The Facility) (Details) $ in Millions	Sep. 30, 2018USD ($)
Summary of the borrowings outstanding and capacity available under the facility
Capacity	$ 3,500
Amount Drawn/ Outstanding	630
Letters of Credit	6
Capacity Available	$ 2,864

Revolving Credit Facilities, _5

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Credit Facilities) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2018	Mar. 31, 2018	Dec. 31, 2017
Amount of total borrowing capacity against which fronting commitments exist	$ 20,000
Amount of Facility	3,500,000
Amount Drawn/ Outstanding	630,000
Entergy Arkansas [Member]
Amount of total borrowing capacity against which fronting commitments exist	5,000
Letters of Credit Outstanding, Amount	$ 1,000		$ 200
Entergy Arkansas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Sep. 14, 2023
Amount of Facility	$ 150,000
Interest Rate	3.49%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Arkansas [Member] | Credit Facility Of Twenty Million [Member]
Expiration Date	Apr. 30, 2019
Amount of Facility	$ 20,000
Interest Rate	3.49%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Louisiana [Member]
Amount of total borrowing capacity against which fronting commitments exist	$ 15,000
Entergy Louisiana [Member] | Credit Facility Of Three Hundred Fifty Million [Member]
Expiration Date	Sep. 14, 2023
Amount of Facility	$ 350,000	$ 350,000
Interest Rate	3.49%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	$ 200		100
Entergy Mississippi [Member] | Credit Facility Of Thirty Seven Point Five Million [Member]
Expiration Date	May 31, 2019
Amount of Facility	$ 37,500
Interest Rate	3.74%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Thirty Five Million [Member]
Expiration Date	May 31, 2019
Amount of Facility	$ 35,000
Interest Rate	3.74%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Ten Million [Member]
Expiration Date	May 31, 2019
Amount of Facility	$ 10,000
Interest Rate	3.74%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy New Orleans [Member]
Amount of total borrowing capacity against which fronting commitments exist	$ 10,000
Entergy New Orleans [Member] | Credit Facility Of Twenty Five Million [Member]
Expiration Date	Nov. 20, 2018
Amount of Facility	$ 25,000
Interest Rate	3.72%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	800
Entergy Texas [Member]
Amount of total borrowing capacity against which fronting commitments exist	30,000
Letters of Credit Outstanding, Amount	$ 3,600		$ 50
Entergy Texas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Sep. 14, 2023
Amount of Facility	$ 150,000
Interest Rate	3.74%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 1,300

Revolving Credit Facilities, _6

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Short-Term Borrowings And The Outstanding Short-Term Borrowings) (Details) $ in Millions	Sep. 30, 2018USD ($)
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	34
Entergy New Orleans [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	150
Borrowings	0
Entergy Texas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	0
System Energy [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	$ 0

Revolving Credit Facilities, _7

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel) (Details) $ in Millions	9 Months Ended
	Sep. 30, 2018USD ($)
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount Drawn/ Outstanding	$ 630
Entergy Arkansas VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Sep. 16, 2021
Amount of Facility	$ 80
Line of Credit Facility, Interest Rate During Period	3.18%
Amount Drawn/ Outstanding	$ 70.4
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
System Energy VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Sep. 16, 2021
Amount of Facility	$ 120
Line of Credit Facility, Interest Rate During Period	3.18%
Amount Drawn/ Outstanding	$ 37.7
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
Entergy Louisiana River Bend VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Sep. 16, 2021
Amount of Facility	$ 105
Line of Credit Facility, Interest Rate During Period	3.18%
Amount Drawn/ Outstanding	$ 34.5
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
Entergy Louisiana Waterford VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Sep. 16, 2021
Amount of Facility	$ 105
Line of Credit Facility, Interest Rate During Period	3.18%
Amount Drawn/ Outstanding	$ 30.5
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%

Revolving Credit Facilities, _8

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Notes Payable By Variable Interest Entities) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Mar. 31, 2018
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 Seven Eight Percent Series I Notes Due October Two Thousand Eighteen [Member] | System Energy VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.78%
Amount	$ 85
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%	3.42%
Amount	$ 100

Revolving Credit Facilities, _9

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Book Value And The Fair Value Of Long-Term Debt) (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Long-term Debt, Fair Value	$ 16,232,180	$ 15,367,453
Long-term Debt, Book Value	16,515,836	15,075,266
Entergy Arkansas [Member]
Long-term Debt, Fair Value	3,031,681	2,865,844
Long-term Debt, Book Value	3,242,282	2,952,399
Long term DOE obligations	186,000	183,000
Entergy Louisiana [Member]
Long-term Debt, Fair Value	6,757,649	6,389,774
Long-term Debt, Book Value	6,761,123	6,144,071
Entergy Mississippi [Member]
Long-term Debt, Fair Value	1,234,124	1,285,741
Long-term Debt, Book Value	1,270,830	1,270,122
Entergy New Orleans [Member]
Long-term Debt, Fair Value	499,764	455,968
Long-term Debt, Book Value	491,570	436,870
Entergy Texas [Member]
Long-term Debt, Fair Value	1,546,101	1,661,902
Long-term Debt, Book Value	1,527,817	1,587,150
System Energy [Member]
Long-term Debt, Fair Value	610,485	529,119
Long-term Debt, Book Value	639,455	551,488
Capital Lease Obligations	$ 34,000	$ 34,000

Revolving Credit Facilities,_10

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations) (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Entergy Arkansas [Member]
Letters of Credit Outstanding, Amount	$ 1,000	$ 200
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	200	100
Entergy Texas [Member]
Letters of Credit Outstanding, Amount	3,600	$ 50
Credit Facility Of Twenty Five Million [Member] | Entergy Arkansas [Member]
Uncommitted Credit Facility	$ 25,000
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 1,000
Credit Facility of Fifty Million [Member] | Entergy Texas [Member]
Uncommitted Credit Facility	$ 50,000
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 20,000
Credit Facility of Forty Million [Member] | Entergy Mississippi [Member]
Uncommitted Credit Facility	$ 40,000
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 11,200
Credit Facility of Fifteen Million [Member] | Entergy New Orleans [Member]
Uncommitted Credit Facility	$ 15,000
Letter of Credit Fee, Percentage	1.00%
Letters of Credit Outstanding, Amount	$ 2,100
Credit Facility Of One Hundred Twenty Five Million [Member] | Entergy Louisiana [Member]
Uncommitted Credit Facility	$ 125,000
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 22,000

Stock Based Compensation (Narra

Stock Based Compensation (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	Jan. 25, 2018	Sep. 30, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option granted (in shares)	687,400
Weighted-average grant-date fair value of options granted (in dollars per share)	$ 6.99
Stock options outstanding		4,071,301
Weighted-average exercise price of stock options outstanding (in dollars per share)		$ 74.53
Intrinsic value in the money stock options		$ 26.9
Vesting period of awards under Entergy's plans, years		3 years
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	333,850
Restricted stock awards granted value (in dollars per share)	$ 78.08
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	182,408
LTIP awards granted value (in dollars per share)	$ 86.75
LTIP awards granted value based on stock price (in dollars per share)	$ 78.08

Stock-Based Compensation (Finan

Stock-Based Compensation (Financial Information For Stock Options) (Details) - Employee Stock Option [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 1.1	$ 1.1	$ 3.3	$ 3.3
Tax benefit recognized in Entergy's net income	0.2	0.5	0.8	1.3
Compensation cost capitalized as part of fixed assets and inventory	$ 0.1	$ 0.2	$ 0.5	$ 0.6

Stock-Based Compensation (Fin_2

Stock-Based Compensation (Financial Information For Other Equity Plans) (Details) - Other Equity Awards [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 8.5	$ 7.6	$ 26	$ 24.1
Tax benefit recognized in Entergy's net income	2.2	3	6.6	9.3
Compensation cost capitalized as part of fixed assets and inventory	$ 2.5	$ 2.1	$ 7.3	$ 6.3

Retirement And Other Postreti_3

Retirement And Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Change on Operating Results		$ 30,000		$ 76,000	$ 101,000	$ 71,000	$ 148,000
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			$ 315,600
Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Change on Operating Results		3,515		9,995	13,668	13,392	30,671
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			51,982
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Change on Operating Results		8,585		20,942	27,796	26,118	50,686
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			58,363
Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Change on Operating Results		778		1,862	2,742	2,424	6,268
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			12,203
Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Change on Operating Results		356		794	1,293	1,014	3,975
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			5,938
Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Change on Operating Results		43		(194)	179	(1,054)	4,000
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			9,323
System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Change on Operating Results		1,521		4,778	$ 6,190	$ 5,088	$ 10,213
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			11,152
Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year								$ 383,500
Subsequent Event [Member] | 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								64,062
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year								12,080
Subsequent Event [Member] | 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								71,919
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year								13,556
Subsequent Event [Member] | 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								14,933
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year								2,730
Subsequent Event [Member] | 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								7,250
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year								1,312
Subsequent Event [Member] | 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								10,883
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year								1,560
Subsequent Event [Member] | 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								13,786
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year								$ 2,634
Non Qualified Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	$ 4,200	15,800	19,700	28,900
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits	212	11,600	7,000	15,500
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	114	111	369	483
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits	7	10	0	173
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	42	46	138	141
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	73	62	230	189
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	20	18	62	55
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	$ 124	529	$ 377
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits			$ 139

Retirement And Other Postreti_4

Retirement And Other Postretirement Benefits (Components Of Qualified Net Pension Cost) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	$ 38,752	$ 33,410	$ 116,256	$ 100,230
Interest cost on projected benefit obligation	66,854	65,206	200,562	195,618
Expected return on assets	(110,535)	(102,056)	(331,605)	(306,168)
Amortization of prior service cost (credit)	99	65	297	195
Amortization of loss	68,526	56,930	205,578	170,790
Net other postretirement benefit cost	63,696	53,555	191,088	160,665
Pension Plans Defined Benefit [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	6,189	5,090	18,567	15,270
Interest cost on projected benefit obligation	13,004	12,944	39,012	38,832
Expected return on assets	(21,851)	(20,427)	(65,553)	(61,281)
Amortization of loss	13,412	11,640	40,236	34,920
Net other postretirement benefit cost	10,754	9,247	32,262	27,741
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	8,446	6,925	25,338	20,775
Interest cost on projected benefit obligation	14,940	14,809	44,820	44,427
Expected return on assets	(24,809)	(23,017)	(74,427)	(69,051)
Amortization of loss	14,450	12,354	43,350	37,062
Net other postretirement benefit cost	13,027	11,071	39,081	33,213
Pension Plans Defined Benefit [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,822	1,472	5,466	4,416
Interest cost on projected benefit obligation	3,769	3,732	11,307	11,196
Expected return on assets	(6,502)	(6,131)	(19,506)	(18,393)
Amortization of loss	3,610	3,053	10,830	9,159
Net other postretirement benefit cost	2,699	2,126	8,097	6,378
Pension Plans Defined Benefit [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	673	625	2,019	1,875
Interest cost on projected benefit obligation	1,813	1,791	5,439	5,373
Expected return on assets	(2,993)	(2,800)	(8,979)	(8,400)
Amortization of loss	1,954	1,658	5,862	4,974
Net other postretirement benefit cost	1,447	1,274	4,341	3,822
Pension Plans Defined Benefit [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,589	1,364	4,767	4,092
Interest cost on projected benefit obligation	3,348	3,392	10,044	10,176
Expected return on assets	(6,523)	(6,180)	(19,569)	(18,540)
Amortization of loss	2,626	2,310	7,878	6,930
Net other postretirement benefit cost	1,040	886	3,120	2,658
Pension Plans Defined Benefit [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,776	1,536	5,328	4,608
Interest cost on projected benefit obligation	3,227	3,091	9,681	9,273
Expected return on assets	(4,991)	(4,663)	(14,973)	(13,989)
Amortization of loss	3,715	2,964	11,145	8,892
Net other postretirement benefit cost	3,727	2,928	11,181	8,784
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	6,782	6,729	20,346	20,187
Interest cost on projected benefit obligation	12,681	13,960	38,043	41,880
Expected return on assets	(10,373)	(9,408)	(31,119)	(28,224)
Amortization of prior service cost (credit)	(9,251)	(10,356)	(27,753)	(31,068)
Amortization of loss	3,432	5,476	10,296	16,428
Net other postretirement benefit cost	3,271	6,401	9,813	19,203
Other Postretirement [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	793	863	2,379	2,589
Interest cost on projected benefit obligation	1,997	2,255	5,991	6,765
Expected return on assets	(4,342)	(3,959)	(13,026)	(11,877)
Amortization of prior service cost (credit)	(1,278)	(1,278)	(3,834)	(3,834)
Amortization of loss	289	1,115	867	3,345
Net other postretirement benefit cost	(2,541)	(1,004)	(7,623)	(3,012)
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,556	1,593	4,668	4,779
Interest cost on projected benefit obligation	2,789	3,025	8,367	9,075
Expected return on assets	0	0	0	0
Amortization of prior service cost (credit)	(1,934)	(1,934)	(5,802)	(5,802)
Amortization of loss	388	465	1,164	1,395
Net other postretirement benefit cost	2,799	3,149	8,397	9,447
Other Postretirement [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	321	290	963	870
Interest cost on projected benefit obligation	683	690	2,049	2,070
Expected return on assets	(1,303)	(1,200)	(3,909)	(3,600)
Amortization of prior service cost (credit)	(456)	(456)	(1,368)	(1,368)
Amortization of loss	377	419	1,131	1,257
Net other postretirement benefit cost	(378)	(257)	(1,134)	(771)
Other Postretirement [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	129	142	387	426
Interest cost on projected benefit obligation	417	469	1,251	1,407
Expected return on assets	(1,313)	(1,159)	(3,939)	(3,477)
Amortization of prior service cost (credit)	(186)	(186)	(558)	(558)
Amortization of loss	34	105	102	315
Net other postretirement benefit cost	(919)	(629)	(2,757)	(1,887)
Other Postretirement [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	330	372	990	1,116
Interest cost on projected benefit obligation	939	1,124	2,817	3,372
Expected return on assets	(2,446)	(2,180)	(7,338)	(6,540)
Amortization of prior service cost (credit)	(579)	(579)	(1,737)	(1,737)
Amortization of loss	206	826	618	2,478
Net other postretirement benefit cost	(1,550)	(437)	(4,650)	(1,311)
Other Postretirement [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	306	320	918	960
Interest cost on projected benefit obligation	500	559	1,500	1,677
Expected return on assets	(783)	(717)	(2,349)	(2,151)
Amortization of prior service cost (credit)	(378)	(378)	(1,134)	(1,134)
Amortization of loss	233	390	699	1,170
Net other postretirement benefit cost	(122)	174	(366)	522
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	4,200	15,800	19,700	28,900
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits	212	11,600	7,000	15,500
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	114	111	369	483
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits	7	10	0	173
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	42	46	138	141
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	73	62	230	189
Non Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	20	18	62	55
Non Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	$ 122	$ 124	529	$ 377
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits			$ 139

Retirement And Other Postreti_5

Retirement And Other Postretirement Benefits (Expected Employer Contributions) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2018	Dec. 31, 2018
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	$ 315,600
Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		$ 383,500
Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	58,363
Entergy Louisiana [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		71,919
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		13,556
Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	12,203
Entergy Mississippi [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		14,933
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		2,730
Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	5,938
Entergy New Orleans [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		7,250
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		1,312
Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	9,323
Entergy Texas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		10,883
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		1,560
System Energy [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	11,152
System Energy [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		13,786
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		2,634
Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	$ 51,982
Entergy Arkansas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		64,062
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		$ 12,080

Retirement And Other Postreti_6

Retirement And Other Postretirement Benefits (Reclassification Out Of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	$ 5,425	$ 6,565	$ 16,278	$ 19,691
Amortization of loss	(24,740)	(21,480)	(74,503)	(64,605)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(76)	(4,200)	(2,098)	(5,965)
Total	(19,391)	(19,115)	(60,323)	(50,879)
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,934	1,934	5,802	5,802
Amortization of loss	(1,257)	(1,332)	(3,770)	(3,996)
Total	677	602	2,032	1,806
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(99)	(65)	(297)	(195)
Amortization of loss	(21,958)	(18,451)	(65,870)	(55,351)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0	0	0	0
Total	(22,057)	(18,516)	(66,167)	(55,546)
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	(867)	(865)	(2,601)	(2,594)
Total	(867)	(865)	(2,601)	(2,594)
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	5,595	6,718	16,786	20,152
Amortization of loss	(1,932)	(2,202)	(5,801)	(6,606)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0	0	0	0
Total	3,663	4,516	10,985	13,546
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,934	1,934	5,802	5,802
Amortization of loss	(388)	(465)	(1,164)	(1,395)
Total	1,546	1,469	4,638	4,407
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(71)	(88)	(211)	(266)
Amortization of loss	(850)	(827)	(2,832)	(2,648)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(76)	(4,200)	(2,098)	(5,965)
Total	(997)	(5,115)	(5,141)	(8,879)
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	(2)	(2)	(5)	(7)
Total	$ (2)	$ (2)	$ (5)	$ (7)

Business Segment Information Bu

Business Segment Information Business Segment Information (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended	48 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2018	Dec. 31, 2022
Segment Reporting Information [Line Items]
Asset Write-Offs, Impairments, And Related Charges	$ 155	$ 16	$ 297	$ 422
Restructuring Charges	43	23	103	89
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	$ 43	$ 23	$ 103	$ 89
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | Subsequent Event [Member]
Segment Reporting Information [Line Items]
Restructuring Charges					$ 155	$ 215

Business Segment Information (S

Business Segment Information (Segment Financial Information) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018		Sep. 30, 2017		Dec. 31, 2017
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 3,104,319	$ 3,243,628	$ 8,496,970		$ 8,450,636
Segment Financial Information
Income taxes (benefits)	(283,006)	241,795	(519,937)		(87,555)
Consolidated net income	539,818	401,644	924,877	[1]	901,064	[1]
Assets	48,471,172		48,471,172				$ 46,707,149
Utility [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,724,279	2,820,421	7,389,477		7,156,865
Segment Financial Information
Income taxes (benefits)	(137,035)	230,647	(325,134)		459,990
Consolidated net income	507,745	403,733	1,104,078		817,738
Assets	44,889,498		44,889,498				42,978,669
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	380,080	423,245	1,107,606		1,293,867
Segment Financial Information
Income taxes (benefits)	(135,659)	25,563	(166,882)		(507,719)
Consolidated net income	105,571	55,765	31,456		252,455
Assets	5,507,013		5,507,013				5,638,009
All Other [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0		0
Segment Financial Information
Income taxes (benefits)	(10,312)	(14,415)	(27,921)		(39,826)
Consolidated net income	(41,601)	(25,956)	(114,962)		(73,434)
Assets	1,274,909		1,274,909				1,011,612
Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(40)	(38)	(113)		(96)
Segment Financial Information
Income taxes (benefits)	0	0	0		0
Consolidated net income	(31,897)	$ (31,898)	(95,695)		$ (95,695)
Assets	$ (3,200,248)		$ (3,200,248)				$ (2,921,141)
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2018 and 2017 include $10.3 million and $10.3 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Business Segment Information _2

Business Segment Information Business Segment Information (Restructuring Costs) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Jun. 30, 2018	Dec. 31, 2017	Jun. 30, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Restructuring Charges	$ 43	$ 23	$ 103	$ 89
Restructuring Reserve	200	73	200	73	$ 157	$ 97	$ 57	$ 91
Payments for Restructuring			0	100
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	43	23	103	89
Restructuring Reserve	186	59	186	59	143	83	36	70
Payments for Restructuring			0	100
Economic Development Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	0	0	0	0
Restructuring Reserve	14	14	14	14	$ 14	$ 14	$ 21	$ 21
Payments for Restructuring			0	0
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Restructuring Reserve, Settled without Cash	0	(7)	0	(7)
Entergy Wholesale Commodities [Member] | Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Reserve, Settled without Cash	0	0	0	0
Entergy Wholesale Commodities [Member] | Economic Development Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Reserve, Settled without Cash	$ 0	$ (7)	$ 0	$ (7)

Risk Management and Fair Valu_3

Risk Management and Fair Values (Narrative) (Details) $ in Thousands, TWh in Millions	3 Months Ended			9 Months Ended		12 Months Ended
	Dec. 31, 2018TWh	Sep. 30, 2018USD ($)GWhMMBTU	Sep. 30, 2017USD ($)	Sep. 30, 2018USD ($)GWhMMBTUcounterparty	Sep. 30, 2017USD ($)	Dec. 31, 2017USD ($)counterparty
Risk Management and Fair Values [Abstract]
Cash flow hedges relating to power sales as part of net unrealized gains				$ (58,000)
Reclassified from accumulated other comprehensive income (OCI) to operating revenues				(47,000)
Maturity of cash flow hedges, Tax		$ (2,000)	$ 8,000	$ (8,000)	$ 30,000
Maximum length of time over which Company is currently hedging the variability in future cash flows for forecasted power transactions, years				2 years 6 months
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		13,814,000		13,814,000
Total volume of fixed transmission rights outstanding | GWh		77,520		77,520
Change in cash flow hedges due to ineffectiveness		$ (3,100)	2,400	$ (5,200)	6,400
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset and Liability Unrealized Gains (Loss) Included in Earnings		1,700	$ 400	1,100	$ 1,000
Entergy Arkansas [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount		$ 1,000		$ 1,000		$ 200
Total volume of fixed transmission rights outstanding | GWh		17,557		17,557
Entergy Louisiana [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		6,300,000		6,300,000
Total volume of fixed transmission rights outstanding | GWh		33,144		33,144
Entergy Mississippi [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount		$ 200		$ 200		100
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		6,790,000		6,790,000
Total volume of fixed transmission rights outstanding | GWh		10,295		10,295
Entergy New Orleans [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		724,000		724,000
Total volume of fixed transmission rights outstanding | GWh		3,758		3,758
Entergy Texas [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount		$ 3,600		$ 3,600		50
Total volume of fixed transmission rights outstanding | GWh		12,441		12,441
Entergy Wholesale Commodities [Member]
Risk Management and Fair Values [Abstract]
Cash collateral posted		$ 30,000		$ 30,000		1,000
Derivative, Collateral, Obligation to Return Cash						4,000
Letters of Credit Held						$ 34,000
Number of Derivative Contract Counterparties in a Liability Position | counterparty				7		8
Dollar amount of hedge contract in a liability position		68,000		$ 68,000		$ 65,000
Utility [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount		$ 5,000		$ 5,000
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	87.00%
Total planned generation for remainder of the period | TWh	6.7

Risk Management and Fair Valu_4

Risk Management and Fair Values (Fair Values Of Derivative Instruments) (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Utility [Member]
Liabilities:
Letters of Credit Outstanding, Amount	$ 5,000
Entergy Wholesale Commodities [Member]
Derivatives, Fair Value [Line Items]
Cash collateral posted	30,000	$ 1,000
Assets:
Derivative, Collateral, Obligation to Return Cash		4,000
Liabilities:
Letters of Credit Held		34,000
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	24,000	17,000
Derivative, Collateral, Right to Reclaim Cash	11,000	14,000
Derivative Liability	13,000	3,000
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	1,000
Derivative, Collateral, Right to Reclaim Cash	0
Derivative Liability	1,000
Other Deferred Debits And Other Assets [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0	5,000
Derivative Asset, Fair Value, Gross Asset	10,000	19,000
Derivative, Collateral, Obligation to Return Cash	10,000	14,000
Prepayments And Other [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0	0
Derivative Asset, Fair Value, Gross Asset	10,000	19,000
Derivative, Collateral, Obligation to Return Cash	10,000	19,000
Prepayments And Other [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0	0
Derivative Asset, Fair Value, Gross Asset	3,000	9,000
Derivative, Collateral, Obligation to Return Cash	3,000	9,000
Prepayments And Other [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1,000
Derivative Asset, Fair Value, Gross Asset	1,000
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	21,000
Derivative Asset, Fair Value, Gross Asset	31,000	22,000
Derivative, Collateral, Obligation to Return Cash	2,000	1,000
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	62,000	86,000
Derivative, Collateral, Right to Reclaim Cash	10,000	20,000
Derivative Liability	52,000	66,000
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	4,000	9,000
Derivative, Collateral, Right to Reclaim Cash	3,000	8,000
Derivative Liability	1,000	1,000
Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		6,000
Derivative, Collateral, Right to Reclaim Cash		0
Derivative Liability		6,000
Entergy Louisiana [Member] | Prepayments And Other [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1,000
Derivative Asset, Fair Value, Gross Asset	1,000
Derivative, Collateral, Obligation to Return Cash	0
Entergy Louisiana [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	12,000	10,200
Derivative Asset, Fair Value, Gross Asset	12,200	11,000
Derivative, Collateral, Obligation to Return Cash	(200)	(800)
Entergy Louisiana [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		5,000
Derivative, Collateral, Right to Reclaim Cash		0
Derivative Liability		5,000
Entergy Mississippi [Member]
Liabilities:
Letters of Credit Outstanding, Amount	200	100
Entergy Mississippi [Member] | Prepayments And Other [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	400
Derivative Asset, Fair Value, Gross Asset	400
Derivative, Collateral, Obligation to Return Cash	0
Entergy Mississippi [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	3,700	2,100
Derivative Asset, Fair Value, Gross Asset	3,700	2,100
Derivative, Collateral, Obligation to Return Cash	0	0
Entergy Mississippi [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		1,200
Derivative, Collateral, Right to Reclaim Cash		0
Derivative Liability		1,200
Entergy New Orleans [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	2,100	2,200
Derivative Asset, Fair Value, Gross Asset	2,100	2,200
Derivative, Collateral, Obligation to Return Cash	0	0
Entergy New Orleans [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		200
Derivative, Collateral, Right to Reclaim Cash		0
Derivative Liability		200
Entergy Arkansas [Member]
Liabilities:
Letters of Credit Outstanding, Amount	1,000	200
Entergy Arkansas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	11,300	3,000
Derivative Asset, Fair Value, Gross Asset	11,600	3,200
Derivative, Collateral, Obligation to Return Cash	(300)	(200)
Entergy Texas [Member]
Liabilities:
Letters of Credit Outstanding, Amount	3,600	50
Entergy Texas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	100	3,400
Derivative Asset, Fair Value, Gross Asset	1,700	3,600
Derivative, Collateral, Obligation to Return Cash	$ (1,600)	$ (200)

Risk Management and Fair Valu_5

Risk Management and Fair Values (Derivative Instruments Designated as Cash Flow Hedges On Consolidated Statements Of Income) (Details) - Competitive Businesses Operating Revenues [Member] - Electricity Swaps And Options [Member] - Cash Flow Hedging [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Effect of Derivative instruments designated as cash flow hedges on consolidated statements of income
Amount of gain (loss) recognized in AOCI (effective portion)	$ (51)	$ 43	$ (40)	$ 136
Amount of gain reclassified from accumulated OCI into income (effective portion)	$ (11)	$ 23	$ (38)	$ 87

Risk Management and Fair Valu_6

Risk Management and Fair Values (Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income) (Details) - Not Designated As Hedging Instrument [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
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	$ (2)	$ 0	$ 2
Amount of gain (loss) recorded in income	(2)	0	0	0
Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recognized in AOCI	0	0	0	0
Amount of gain (loss) recorded in income	0	(3)	5	(20)
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	31	28	104	103
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	10.1	4.2	20.1	19.3
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	(0.7)	(2.6)	4.2	(16.3)
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	13.8	9.4	57.2	38.9
Entergy Mississippi [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	0.1	(0.6)	0.9	(3.1)
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	5.4	4.7	23	16.3
Entergy New Orleans [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income				(0.1)
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	2	1.9	10.5	7.7
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	$ (0.4)	$ 7	$ (5.6)	$ 19.2

Risk Management and Fair Valu_7

Risk Management and Fair Values (Assets And Liabilities At Fair Value On A Recurring Basis) (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	$ 923,194	$ 724,644
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	58,000	45,000
Replacement Reserve Escrow	401,000	406,000
Equity Securities, FV-NI	1,569,000	526,000
Debt Securities	2,845,000	2,550,000
Available-for-sale Securities		7,212,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	8,856,000	8,414,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure		76,000
Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		6,000
Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis	67,000
Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	3,030,000	4,136,000
Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		5,000
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		70,000
Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	1,000
Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	29,000	21,000
Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	923,000	725,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	58,000	45,000
Replacement Reserve Escrow	401,000	406,000
Equity Securities, FV-NI	1,569,000	526,000
Debt Securities	1,167,000	1,125,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	4,119,000	2,827,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure		6,000
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		6,000
Fair Value Inputs Level 1 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis	0
Fair Value Inputs Level 1 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		0
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	1,000
Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
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	1,678,000	1,425,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,678,000	1,425,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure		0
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0
Fair Value, Inputs, Level 2 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis	0
Fair Value, Inputs, Level 2 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		0
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0
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	29,000	26,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure		70,000
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0
Fair Value, Inputs, Level 3 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis	67,000
Fair Value, Inputs, Level 3 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		5,000
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		70,000
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0
Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	29,000	21,000
Entergy Mississippi [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	7	4,489
Assets at fair value on a recurring basis
Replacement Reserve Escrow	32,300	32,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	36,400	38,600
Entergy Mississippi [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		1,200
Entergy Mississippi [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0
Entergy Mississippi [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	3,700	2,100
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		4,500
Assets at fair value on a recurring basis
Replacement Reserve Escrow	32,300	32,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	32,700	36,500
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		1,200
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0
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] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0
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	3,700	2,100
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	3,700	2,100
Entergy Louisiana [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	213,222	30,071
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	10,000	2,000
Replacement Reserve Escrow	288,100	289,500
Equity Securities, FV-NI	12,900	15,200
Debt Securities	520,500	493,800
Available-for-sale Securities		1,312,100
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,919,500	1,643,900
Entergy Louisiana [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		5,000
Entergy Louisiana [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	861,800	803,100
Entergy Louisiana [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	1,000
Entergy Louisiana [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	12,000	10,200
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	213,200	30,100
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	10,000	2,000
Replacement Reserve Escrow	288,100	289,500
Equity Securities, FV-NI	12,900	15,200
Debt Securities	157,900	143,300
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	683,100	480,100
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		5,000
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	1,000
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	0	0
Debt Securities	362,600	350,500
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	362,600	350,500
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		0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0
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	0	0
Debt Securities	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	12,000	10,200
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	12,000	10,200
Entergy Arkansas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	208,661	32
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	8,570	3,748
Replacement Reserve Escrow		2,400
Equity Securities, FV-NI	2,200	11,700
Debt Securities	378,500	348,200
Available-for-sale Securities		944,900
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,225,500	954,000
Entergy Arkansas [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	616,200	585,000
Entergy Arkansas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	11,300	3,000
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	208,700
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	8,600	3,700
Replacement Reserve Escrow		2,400
Equity Securities, FV-NI	2,200	11,700
Debt Securities	111,000	115,800
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	330,500	133,600
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
Replacement Reserve Escrow		0
Equity Securities, FV-NI	0	0
Debt Securities	267,500	232,400
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	267,500	232,400
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
Replacement Reserve Escrow		0
Equity Securities, FV-NI	0	0
Debt Securities	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	11,300	3,000
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	11,300	3,000
Entergy New Orleans [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Temporary Cash Investments Fair Value	32,900
Cash Equivalents, at Carrying Value	32,894	32,711
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	5,570	1,455
Replacement Reserve Escrow	80,400	81,900
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	121,000	118,300
Entergy New Orleans [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		200
Entergy New Orleans [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	2,100	2,200
Entergy New Orleans [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	32,900
Cash Equivalents, at Carrying Value		32,700
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	5,600	1,500
Replacement Reserve Escrow	80,400	81,900
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	118,900	116,100
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		200
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]
Temporary Cash Investments Fair Value	0
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]
Temporary Cash Investments Fair Value	0
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	2,100	2,200
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	2,100	2,200
Entergy Texas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	18,956	115,481
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	33,675	37,683
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	52,800	156,600
Entergy Texas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	3,400
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	19,000	115,500
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	33,700	37,700
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	52,700	153,200
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Assets 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	0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Assets 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	3,400
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0	3,400
System Energy [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	254,388	287,109
Assets at fair value on a recurring basis
Equity Securities, FV-NI	7,400	3,100
Debt Securities	359,200	330,500
Available-for-sale Securities		905,700
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,206,800	1,192,800
System Energy [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	585,800	572,100
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	254,400	287,100
Assets at fair value on a recurring basis
Equity Securities, FV-NI	7,400	3,100
Debt Securities	211,100	187,200
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	472,900	477,400
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	0	0
Debt Securities	148,100	143,300
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	148,100	143,300
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	0	0
Debt Securities	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	$ 0	$ 0

Risk Management and Fair Valu_8

Risk Management and Fair Values (Reconciliation Of Changes In The Net Assets (Liabilities) For The Fair Value Of Derivatives Classified As Level 3 In The Fair Value Hierarchy) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Jun. 30, 2018	Dec. 31, 2017	Jun. 30, 2017	Dec. 31, 2016
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value	$ 67		$ 67
Issuance of Financial Transmission Rights			0	$ 0
Electricity Swaps And Options [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value		$ 60		60	$ (25)		$ 38	$ 5
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value	(67)		(67)			$ (65)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings		2		6
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings	(4)		(5)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)		43		136
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Other Comprehensive Income (Loss)	(51)		(40)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	0	0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements		23		87
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	(13)		(43)
Fixed Transmission Rights (FTRs) [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	29	37	29	37	41	21	57	21
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	0	0	(1)	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	19	8	67	56
Issuance of Financial Transmission Rights			46	62
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	31	28	104	103
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	11.3	4.4	11.3	4.4	10.5	3	8.3	5.4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				9.4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	10.9	0.3	16.6
Issuance of Financial Transmission Rights			11.8	8.9
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	10.1	4.2	20.1	19.3
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	12	18.8	12	18.8	18.2	10.2	28.3	8.5
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				18.2
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	7.6		39
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included as Regulatory Liability/Asset		(0.1)
Issuance of Financial Transmission Rights			20	31
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	13.8	9.4	57.2	38.9
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	3.7	5.5	3.7	5.5	4.4	2.1	9.1	3.2
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				9
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	4.7	1.1	20.1
Issuance of Financial Transmission Rights			4.5	9.6
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	5.4	4.7	23	16.3
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	2.1	3.5	2.1	3.5	3	2.2	5.2	1.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				5.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	1.1	0.2	6.7
Issuance of Financial Transmission Rights			3.7	5
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	2	1.9	10.5	7.7
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	0.1	5	0.1	5	$ 4.7	$ 3.4	$ 5.5	$ 3.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				14
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset		6.5
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included as Regulatory Liability/Asset	(5)		(15)
Issuance of Financial Transmission Rights			6.1	7.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	$ 0.4	$ 7	$ 5.6	$ 19.2

Risk Management and Fair Valu_9

Risk Management and Fair Values (Schedules Of Valuation Techniques) (Details) $ in Millions	Sep. 30, 2018USD ($)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value	$ (67)
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		9 Months Ended		12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017	Jan. 01, 2018
Debt Securities, Trading, Measurement Input	$ 397,000		$ 397,000
Decommissioning Trust Funds [Abstract]
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax						$ (632,617)
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts	(825)	$ 30,644	1,708	$ 72,808
Amortized cost of debt securities	$ 2,489,000		$ 2,489,000		$ 2,539,000
Average coupon rate of debt securities	3.36%		3.36%
Average duration of debt securities, years			5 years 358 days
Average maturity of debt securities, years			10 years 146 days
Proceeds from the dispositions of debt securities	$ 2,377,000	440,000	$ 4,178,000	1,903,000
Gains from dispositions of debt securities, gross	4,000	9,000	6,000	79,000
Losses from dispositions of debt securities, gross	15,000	2,000	37,000	9,000
Equity Securities, FV-NI, Unrealized Gain	369,000		464,000
Equity Securities [Member]
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts					472,000
Debt Securities [Member]
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts			(6,000)		7,000
Entergy Arkansas [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 389,200		$ 389,200		349,100
Average coupon rate of debt securities	2.68%		2.68%
Average duration of debt securities, years			4 years 219 days
Average maturity of debt securities, years			6 years 172 days
Proceeds from the dispositions of debt securities	$ 137,900	51,900	$ 259,300	219,200
Gains from dispositions of debt securities, gross	10	0	100	11,700
Losses from dispositions of debt securities, gross	600	0	3,000	200
Equity Securities, FV-NI, Unrealized Gain	37,800		46,000
Entergy Louisiana [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 527,800		$ 527,800		490,000
Average coupon rate of debt securities	4.07%		4.07%
Average duration of debt securities, years			6 years 271 days
Average maturity of debt securities, years			13 years 274 days
Proceeds from the dispositions of debt securities	$ 773,900	50,500	$ 943,300	176,100
Gains from dispositions of debt securities, gross	1,900	2,900	2,500	7,900
Losses from dispositions of debt securities, gross	3,600	100	$ 4,800	400
Percentage Interest in River Bend			30.00%
Equity Securities, FV-NI, Unrealized Gain	55,000		$ 66,300
System Energy [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 365,500		$ 365,500		327,500
Average coupon rate of debt securities	2.95%		2.95%
Average duration of debt securities, years			6 years 73 days
Average maturity of debt securities, years			9 years 29 days
Proceeds from the dispositions of debt securities	$ 157,800	54,600	$ 357,200	308,100
Gains from dispositions of debt securities, gross	0	200	300	700
Losses from dispositions of debt securities, gross	300	$ 200	4,800	$ 1,500
Equity Securities, FV-NI, Unrealized Gain	35,900		43,800
Indian Point 3 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	835,000		835,000		798,000
Indian Point 1 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	509,000		509,000		491,000
Indian Point 2 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	644,000		644,000		621,000
Palisades [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	476,000		476,000		458,000
Pilgrim [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	1,081,000		1,081,000		1,068,000
Vermont Yankee [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	$ 554,000		$ 554,000		$ 613,000

Decommissioning Trust Funds (Se

Decommissioning Trust Funds (Securities Held) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Debt Securities, Available-for-sale [Line Items]
Fair Value		$ 7,212
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		2,175
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax		17
Equity Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value		4,662
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		2,131
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax		1
Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	$ 2,448	2,550
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	10	44
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	51	16
Entergy Arkansas [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value		944.9
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		357
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax		3
Entergy Arkansas [Member] | Equity Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value		596.7
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		354.9
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax		0
Entergy Arkansas [Member] | Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	378.5	348.2
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	0.2	2.1
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	10.9	3
Entergy Louisiana [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value		1,312.1
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		472.1
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax		3.6
Entergy Louisiana [Member] | Equity Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value		818.3
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		461.2
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax		0
Entergy Louisiana [Member] | Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	520.5	493.8
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	2	10.9
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	9.3	3.6
System Energy [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value		905.7
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		312.8
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax		1.2
System Energy [Member] | Equity Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value		575.2
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		308.6
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax		0
System Energy [Member] | Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	359.2	330.5
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	0.9	4.2
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	$ 7.1	$ 1.2

Decommissioning Trust Funds (Av

Decommissioning Trust Funds (Available For Sale Securities Continuous Unrealized Loss Position Fair Value) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Equity Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value		$ 8
More than 12 months Fair Value		0
Total Fair Value		8
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss		1
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss		0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss		1
Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	$ 1,691	1,099
More than 12 months Fair Value	357	265
Total Fair Value	2,048	1,364
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	33	7
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	18	9
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	51	16
Entergy Arkansas [Member] | Equity Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value		0
More than 12 months Fair Value		0
Total Fair Value		0
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss		0
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss		0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss		0
Entergy Arkansas [Member] | Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	259.7	168
More than 12 months Fair Value	78.2	41.4
Total Fair Value	337.9	209.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	6.8	1.2
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	4.1	1.8
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	10.9	3
Entergy Louisiana [Member] | Equity Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value		0
More than 12 months Fair Value		0
Total Fair Value		0
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss		0
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss		0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss		0
Entergy Louisiana [Member] | Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	355.6	135.3
More than 12 months Fair Value	74	84.4
Total Fair Value	429.6	219.7
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	5.8	1.1
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	3.5	2.5
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	9.3	3.6
System Energy [Member] | Equity Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value		0
More than 12 months Fair Value		0
Total Fair Value		0
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss		0
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss		0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss		0
System Energy [Member] | Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	267.6	196.9
More than 12 months Fair Value	34.3	10.4
Total Fair Value	301.9	207.3
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	5.2	1
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	1.9	0.2
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	$ 7.1	$ 1.2

Decommissioning Trust Funds (Fa

Decommissioning Trust Funds (Fair Value Of Debt Securities By Contractual Maturities) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Fair value of debt securities by contractual maturities
Less than 1 year	$ 119	$ 74
1 year - 5 years	934	902
5 years - 10 years	628	812
10 years - 15 years	108	147
15 years - 20 years	92	100
20 years+	567	515
Total	2,448	2,550
Entergy Arkansas [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	40.8	13
1 year - 5 years	174.4	123.4
5 years - 10 years	115.6	180.6
10 years - 15 years	10.6	4.8
15 years - 20 years	5.8	3.4
20 years+	31.3	23
Total	378.5	348.2
Entergy Louisiana [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	22.4	23.2
1 year - 5 years	122	122.8
5 years - 10 years	117.9	109.3
10 years - 15 years	37.7	52.7
15 years - 20 years	41.3	50.7
20 years+	179.2	135.1
Total	520.5	493.8
System Energy [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	2.2	4.1
1 year - 5 years	195.4	173
5 years - 10 years	78.2	78.5
10 years - 15 years	5.6	1
15 years - 20 years	11	6.9
20 years+	66.8	67
Total	$ 359.2	$ 330.5

Income Taxes Income Taxes (Narr

Income Taxes Income Taxes (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended	9 Months Ended
	Jun. 30, 2018	Sep. 30, 2018	Sep. 30, 2018	Dec. 31, 2017
Entergy Arkansas [Member]
Reduction to regulatory liability for income taxes resulting from return of unprotected excess ADIT		$ 153	$ 260
Entergy Louisiana [Member]
Tax benefits related to Hurricane Katrina and Hurricane Rita contingent sharing obligation	$ 52
Unrecognized Tax Benefits		855	855	$ 926
Reduction to regulatory liability for income taxes resulting from return of unprotected excess ADIT		55	86
Entergy Mississippi [Member]
Reduction to regulatory liability for income taxes resulting from return of unprotected excess ADIT		32	161
Entergy New Orleans [Member]
Reduction to regulatory liability for income taxes resulting from return of unprotected excess ADIT		9	9
System Energy [Member]
Reduction to regulatory liability for income taxes resulting from return of unprotected excess ADIT		34	46
Entergy Texas [Member]
Regulatory liability for protected excess ADIT		269	269
Regulatory liability for unprotected excess ADIT		201	$ 201
Entergy Wholesale Commodities [Member]
Reduction of Income Tax Expense, Net of Unrecognized Tax Benefits, Resulting From Tax Election		107
Tax Adjustments, Settlements, and Unusual Provisions		$ 23

Property, Plant, And Equipment

Property, Plant, And Equipment (Narrative) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Construction expenditures in accounts payable	$ 255	$ 368
Entergy Arkansas [Member]
Construction expenditures in accounts payable	27.8	58.8
Entergy Louisiana [Member]
Construction expenditures in accounts payable	80.1	160.4
Entergy Mississippi [Member]
Construction expenditures in accounts payable	8.9	17.1
Entergy New Orleans [Member]
Construction expenditures in accounts payable	18.7	2.5
Entergy Texas [Member]
Construction expenditures in accounts payable	13.9	32.8
System Energy [Member]
Construction expenditures in accounts payable	$ 38.1	$ 33.9

Variable Interest Entities (Nar

Variable Interest Entities (Narrative) (Details) - Grand Gulf [Member] - System Energy [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
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	$ 17.2	$ 17.2

Revenue Recognition (Disaggrega

Revenue Recognition (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Revenue from Contract with Customer, Excluding Assessed Tax		$ 3,104,319	$ 3,243,628	$ 8,496,970	$ 8,450,636
Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		2,697,887	2,793,798	7,276,374	7,056,758
Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		26,352	26,585	112,990	100,011
Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		380,080	423,245	1,107,606	1,293,867
Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		1,138,744		2,799,539
Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		693,760		1,871,380
Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		682,823		1,904,828
Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		60,647		173,949
Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	76,247		214,984
Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[2]	42,847		289,668
Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[3]	2,819		22,026
Non-Customer [Member] | Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[3]	(27,683)		(40,854)
Competitive Business Sales [Member] | Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	407,763		1,148,460
Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		2,575,974		6,749,696
Entergy Arkansas [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		568,399		1,614,028
Entergy Arkansas [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		568,399	673,226	1,614,028	1,644,239
Entergy Arkansas [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		0		0
Entergy Arkansas [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		250,081		644,735
Entergy Arkansas [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		119,950		334,325
Entergy Arkansas [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		126,079		335,529
Entergy Arkansas [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		4,445		12,859
Entergy Arkansas [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	60,338		179,637
Entergy Arkansas [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[2]	4,446		98,571
Entergy Arkansas [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[3]	3,060		8,372
Entergy Arkansas [Member] | Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		500,555		1,327,448
Entergy Louisiana [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		1,206,612	1,290,494	3,308,744	3,254,711
Entergy Louisiana [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		1,196,278	1,280,475	3,263,073	3,216,677
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		10,334	10,019	45,671	38,034
Entergy Louisiana [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		408,680		972,113
Entergy Louisiana [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		272,985		719,652
Entergy Louisiana [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		393,884		1,114,898
Entergy Louisiana [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		17,566		51,581
Entergy Louisiana [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	71,634		272,690
Entergy Louisiana [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[2]	34,220		124,749
Entergy Louisiana [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[3]	(2,691)		7,390
Entergy Louisiana [Member] | Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		1,093,115		2,858,244
Entergy Mississippi [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		367,734		1,037,166
Entergy Mississippi [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		367,734	349,197	1,037,166	898,852
Entergy Mississippi [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		0		0
Entergy Mississippi [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		170,258		451,331
Entergy Mississippi [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		126,987		354,799
Entergy Mississippi [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		44,383		133,012
Entergy Mississippi [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		11,488		33,788
Entergy Mississippi [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	7,876		21,645
Entergy Mississippi [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[2]	4,079		35,055
Entergy Mississippi [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[3]	2,663		7,536
Entergy Mississippi [Member] | Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		353,116		972,930
Entergy New Orleans [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		200,182	199,017	566,903	544,228
Entergy New Orleans [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		184,164	182,451	499,584	482,251
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		16,018	16,566	67,319	61,977
Entergy New Orleans [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		86,014		208,821
Entergy New Orleans [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		62,428		171,224
Entergy New Orleans [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		9,655		26,493
Entergy New Orleans [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		20,364		56,503
Entergy New Orleans [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	4,863		24,390
Entergy New Orleans [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[2]	(1,107)		7,404
Entergy New Orleans [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[3]	1,947		4,749
Entergy New Orleans [Member] | Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		178,461		463,041
Entergy Texas [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		477,231		1,229,657
Entergy Texas [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		477,231	432,909	1,229,657	1,175,324
Entergy Texas [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		0		0
Entergy Texas [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		223,711		522,539
Entergy Texas [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		111,409		291,380
Entergy Texas [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		108,823		294,896
Entergy Texas [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		6,785		19,218
Entergy Texas [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[1]	23,290		71,828
Entergy Texas [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[2]	2,735		28,468
Entergy Texas [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	[3]	478		1,328
Entergy Texas [Member] | Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		450,728		1,128,033
System Energy [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax		$ 78,965	$ 156,106	$ 339,864	$ 475,849
[1]	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.
[2]	Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.
[3]	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.

Revenue Recognition Revenue R_2

Revenue Recognition Revenue Recognition (Narrative) (Details) - $ / MWh	1 Months Ended	9 Months Ended	192 Months Ended
	May 31, 2018	Sep. 30, 2018	Dec. 31, 2022
System Energy [Member]
Percent Interest in Grand Gulf	11.50%	90.00%
Palisades [Member] | Subsequent Event [Member]
Maximum escalated power purchase agreement price per megawatt hour			61.50

Asset Retirement Obligations _2

Asset Retirement Obligations Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Mar. 31, 2018
Entergy Louisiana [Member]
Increase in decommissioning liability		$ 85.4
Pilgrim [Member]
Increase in decommissioning liability	$ 117.5

Uncategorized Items - etr-20180

Label	Element	Value
Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	$ 7,936,155,000
Common Stock [Member]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
Common Stock [Member] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	2,548,000
AOCI Attributable to Parent [Member]
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax	us-gaap_AccumulatedOtherComprehensiveIncomeLossFinancialLiabilityFairValueOptionAfterTax	(632,617,000)
AOCI Attributable to Parent [Member] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	(656,148,000)
Treasury Stock [Member]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
Treasury Stock [Member] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	(5,397,637,000)
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
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
Retained Earnings [Member]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	576,257,000	[1]
Retained Earnings [Member] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	8,553,959,000
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	[1]
Subsidiaries Preferred Stock [Member] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	$ 0
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2018 and 2017 include $10.3 million and $10.3 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.