System Energy Resources 10-Q 4 Nov 16 2016 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2016	Oct. 31, 2016
Entity Registrant Name	ENTERGY CORP /DE/
Entity Central Index Key	65,984
Document Type	10-Q
Document Period End Date	Sep. 30, 2016
Amendment Flag	false
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		179,127,892
Entergy Arkansas [Member]
Entity Registrant Name	ENTERGY ARKANSAS, INC.
Entity Central Index Key	7,323
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
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 Well-known Seasoned Issuer	Yes
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 Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Entergy New Orleans [Member]
Entity Registrant Name	ENTERGY NEW ORLEANS, INC.
Entity Central Index Key	71,508
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
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 Well-known Seasoned Issuer	No
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 Well-known Seasoned Issuer	No
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, 2016	Sep. 30, 2015	Sep. 30, 2016		Sep. 30, 2015
OPERATING REVENUES
Electric	$ 2,624,562	$ 2,825,143	$ 6,760,054		$ 7,289,280
Natural gas	24,796	24,517	95,530		111,805
Competitive businesses	475,345	521,746	1,341,534		1,603,643
TOTAL	3,124,703	3,371,406	8,197,118		9,004,728
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	460,990	739,449	1,347,422		1,919,605
Purchased power	375,107	449,784	880,102		1,114,736
Nuclear refueling outage expenses	56,675	68,577	154,951		200,575
Other operation and maintenance	833,176	852,385	2,324,350		2,450,368
Asset Write-Offs, Impairments, And Related Charges	18,841	1,642,204	33,170		1,642,204
Decommissioning	85,266	68,888	230,519		207,617
Taxes other than income taxes	149,076	158,134	448,103		472,035
Depreciation and amortization	340,399	334,841	1,010,339		1,007,181
Other regulatory charges (credits) - net	33,113	22,160	55,626		35,271
TOTAL	2,352,643	4,336,422	6,484,582		9,049,592
OPERATING INCOME (LOSS)	772,060	(965,016)	1,712,536		(44,864)
OTHER INCOME
Allowance for equity funds used during construction	15,451	14,129	48,242		37,841
Investment Income, Net	37,534	39,054	116,662		146,893
Miscellaneous - net	(6,740)	(10,005)	(25,702)		(34,769)
TOTAL	46,245	43,178	139,202		149,965
INTEREST EXPENSE
Interest expense	174,902	171,349	526,344		503,546
Allowance for borrowed funds used during construction	(7,707)	(7,289)	(24,520)		(19,450)
TOTAL	167,195	164,060	501,824		484,096
INCOME (LOSS) BEFORE INCOME TAXES	651,110	(1,085,898)	1,349,914		(378,995)
Income taxes	257,906	(367,665)	148,879		(117,412)
CONSOLIDATED NET INCOME (LOSS)	393,204	(718,233)	1,201,035	[1]	(261,583)	[1]
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	5,034	4,794	15,586		14,552
EARNINGS APPLICABLE TO COMMON STOCK	$ 388,170	$ (723,027)	$ 1,185,449		$ (276,135)
Earnings (loss) per average common share:
Basic (in dollars per share)	$ 2.17	$ (4.04)	$ 6.63		$ (1.54)
Diluted (in dollars per share)	2.16	(4.04)	6.60		(1.54)
Dividends declared per common share (in dollars per share)	$ 0.85	$ 0.83	$ 2.55		$ 2.49
Basic average number of common shares outstanding (in shares)	179,023,351	179,151,832	178,804,148		179,442,172
Diluted average number of common shares outstanding (in shares)	179,990,888	179,151,832	179,490,060		179,442,172
Entergy Arkansas [Member]
OPERATING REVENUES
Electric	$ 654,599	$ 714,353	$ 1,624,224		$ 1,777,415
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	105,147	176,164	274,106		426,351
Purchased power	52,023	105,321	163,541		285,806
Nuclear refueling outage expenses	14,554	13,603	44,604		39,109
Other operation and maintenance	187,294	214,536	514,109		544,446
Decommissioning	13,504	12,713	39,908		37,508
Taxes other than income taxes	24,931	28,905	70,978		77,589
Depreciation and amortization	67,309	61,527	197,597		183,169
Other regulatory charges (credits) - net	1,177	(7,652)	2,896		(17,604)
TOTAL	465,939	605,117	1,307,739		1,576,374
OPERATING INCOME (LOSS)	188,660	109,236	316,485		201,041
OTHER INCOME
Allowance for equity funds used during construction	3,734	3,950	12,661		9,856
Investment Income, Net	5,410	4,541	14,774		18,354
Miscellaneous - net	812	(1,036)	(983)		(1,724)
TOTAL	9,956	7,455	26,452		26,486
INTEREST EXPENSE
Interest expense	28,152	26,360	88,726		79,264
Allowance for borrowed funds used during construction	(2,000)	(2,246)	(6,851)		(5,321)
TOTAL	26,152	24,114	81,875		73,943
INCOME (LOSS) BEFORE INCOME TAXES	172,464	92,577	261,062		153,584
Income taxes	62,316	36,915	97,729		58,532
CONSOLIDATED NET INCOME (LOSS)	110,148	55,662	163,333		95,052
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	1,476	1,718	4,913		5,155
EARNINGS APPLICABLE TO COMMON STOCK	108,672	53,944	158,420		89,897
Entergy Louisiana [Member]
OPERATING REVENUES
Electric	1,240,217	1,289,642	3,166,380		3,398,781
Natural gas	9,235	8,840	37,251		43,491
TOTAL	1,249,452	1,298,482	3,203,631		3,442,272
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	261,979	250,482	616,402		647,131
Purchased power	261,212	341,198	677,309		901,957
Nuclear refueling outage expenses	12,894	11,248	38,648		34,187
Other operation and maintenance	229,717	231,333	668,738		700,411
Decommissioning	11,812	10,936	34,978		32,365
Taxes other than income taxes	38,129	44,143	124,857		128,204
Depreciation and amortization	114,251	109,562	336,294		327,188
Other regulatory charges (credits) - net	6,507	5,144	18,084		(451)
TOTAL	936,501	1,004,046	2,515,310		2,770,992
OPERATING INCOME (LOSS)	312,951	294,436	688,321		671,280
OTHER INCOME
Allowance for equity funds used during construction	6,735	5,499	18,479		15,194
Investment Income, Net	38,731	37,632	116,398		112,429
Miscellaneous - net	(4,429)	(2,976)	(10,044)		(7,764)
TOTAL	41,037	40,155	124,833		119,859
INTEREST EXPENSE
Interest expense	68,396	64,417	204,259		194,701
Allowance for borrowed funds used during construction	(3,455)	(3,034)	(9,735)		(8,527)
TOTAL	64,941	61,383	194,524		186,174
INCOME (LOSS) BEFORE INCOME TAXES	289,047	273,208	618,630		604,965
Income taxes	99,541	86,068	64,193		182,735
CONSOLIDATED NET INCOME (LOSS)	189,506	187,140	554,437		422,230
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	0	1,850	0		5,737
EARNINGS APPLICABLE TO COMMON STOCK	189,506	185,290	554,437		416,493
Entergy Mississippi [Member]
OPERATING REVENUES
Electric	309,739	410,743	820,923		1,116,533
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	3,444	89,512	64,790		244,331
Purchased power	87,070	120,697	216,814		308,618
Other operation and maintenance	67,155	60,504	178,809		190,690
Taxes other than income taxes	24,837	24,082	68,821		72,219
Depreciation and amortization	34,438	32,459	101,746		95,888
Other regulatory charges (credits) - net	4,483	9,225	(1,832)		17,598
TOTAL	221,427	336,479	629,148		929,344
OPERATING INCOME (LOSS)	88,312	74,264	191,775		187,189
OTHER INCOME
Allowance for equity funds used during construction	1,441	713	4,072		2,094
Investment Income, Net	129	50	490		105
Miscellaneous - net	(849)	(743)	(2,604)		(2,675)
TOTAL	721	20	1,958		(476)
INTEREST EXPENSE
Interest expense	13,866	14,527	43,866		43,164
Allowance for borrowed funds used during construction	(741)	(376)	(2,099)		(1,117)
TOTAL	13,125	14,151	41,767		42,047
INCOME (LOSS) BEFORE INCOME TAXES	75,908	60,133	151,966		144,666
Income taxes	29,296	23,557	56,042		56,876
CONSOLIDATED NET INCOME (LOSS)	46,612	36,576	95,924		87,790
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	707	707	2,121		2,121
EARNINGS APPLICABLE TO COMMON STOCK	45,905	35,869	93,803		85,669
Entergy New Orleans [Member]
OPERATING REVENUES
Electric	185,775	194,056	457,317		458,796
Natural gas	15,561	15,677	58,279		68,314
TOTAL	201,336	209,733	515,596		527,110
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	19,231	44,085	42,706		81,807
Purchased power	82,581	75,107	221,689		209,626
Other operation and maintenance	27,251	29,792	78,752		89,872
Taxes other than income taxes	13,409	13,134	35,846		36,302
Depreciation and amortization	13,047	10,929	38,719		32,529
Other regulatory charges (credits) - net	3,538	1,952	6,812		1,340
TOTAL	159,057	174,999	424,524		451,476
OPERATING INCOME (LOSS)	42,279	34,734	91,072		75,634
OTHER INCOME
Allowance for equity funds used during construction	311	389	767		1,022
Investment Income, Net	58	15	157		53
Miscellaneous - net	(92)	(81)	(144)		532
TOTAL	277	323	780		1,607
INTEREST EXPENSE
Interest expense	5,373	4,480	15,730		13,086
Allowance for borrowed funds used during construction	(116)	(177)	(291)		(471)
TOTAL	5,257	4,303	15,439		12,615
INCOME (LOSS) BEFORE INCOME TAXES	37,299	30,754	76,413		64,626
Income taxes	13,598	11,591	29,701		23,275
CONSOLIDATED NET INCOME (LOSS)	23,701	19,163	46,712		41,351
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	241	241	724		724
EARNINGS APPLICABLE TO COMMON STOCK	23,460	18,922	45,988		40,627
Entergy Texas [Member]
OPERATING REVENUES
Electric	442,085	498,249	1,233,311		1,312,381
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	21,919	72,850	185,801		197,017
Purchased power	189,213	202,864	486,696		557,912
Other operation and maintenance	50,536	65,253	157,706		187,840
Taxes other than income taxes	17,486	18,644	54,081		54,555
Depreciation and amortization	27,412	25,795	79,526		76,356
Other regulatory charges (credits) - net	27,555	26,219	62,229		64,000
TOTAL	334,121	411,625	1,026,039		1,137,680
OPERATING INCOME (LOSS)	107,964	86,624	207,272		174,701
OTHER INCOME
Allowance for equity funds used during construction	1,472	1,371	6,174		3,912
Investment Income, Net	221	(5)	689		(411)
Miscellaneous - net	(256)	(133)	(726)		(247)
TOTAL	1,437	1,233	6,137		3,254
INTEREST EXPENSE
Interest expense	22,416	21,917	65,993		64,475
Allowance for borrowed funds used during construction	(954)	(886)	(4,008)		(2,542)
TOTAL	21,462	21,031	61,985		61,933
INCOME (LOSS) BEFORE INCOME TAXES	87,939	66,826	151,424		116,022
Income taxes	31,806	23,512	56,671		41,227
CONSOLIDATED NET INCOME (LOSS)	56,133	43,314	94,753		74,795
System Energy [Member]
OPERATING REVENUES
Electric	114,039	155,899	403,056		475,039
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	(7,393)	22,984	26,429		66,400
Nuclear refueling outage expenses	4,958	5,244	14,448		16,346
Other operation and maintenance	32,867	39,520	100,793		116,309
Decommissioning	12,802	12,095	37,782		35,695
Taxes other than income taxes	6,256	6,497	18,894		20,263
Depreciation and amortization	30,811	35,091	100,902		109,398
Other regulatory charges (credits) - net	(10,148)	(12,667)	(32,564)		(29,761)
TOTAL	70,153	108,764	266,684		334,650
OPERATING INCOME (LOSS)	43,886	47,135	136,372		140,389
OTHER INCOME
Allowance for equity funds used during construction	1,758	2,252	6,089		5,945
Investment Income, Net	4,233	4,732	12,631		12,195
Miscellaneous - net	(109)	(129)	(365)		(567)
TOTAL	5,882	6,855	18,355		17,573
INTEREST EXPENSE
Interest expense	9,186	10,404	28,119		35,764
Allowance for borrowed funds used during construction	(440)	(595)	(1,536)		(1,571)
TOTAL	8,746	9,809	26,583		34,193
INCOME (LOSS) BEFORE INCOME TAXES	41,022	44,181	128,144		123,769
Income taxes	18,652	18,958	54,726		51,153
CONSOLIDATED NET INCOME (LOSS)	$ 22,370	$ 25,223	$ 73,418		$ 72,616
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $15.6 million and $9.6 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015
OPERATING ACTIVITIES
Consolidated net income (loss)	[1]	$ 1,201,035	$ (261,583)
Adjustments to reconcile consolidated net income (loss) to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		1,548,872	1,612,690
Deferred income taxes, investment tax credits, and non-current taxes accrued		119,603	(267,984)
Impairment of Long-Lived Assets Held-for-use		33,170	1,642,204
Changes in working capital:
Receivables		(270,847)	(222,311)
Fuel inventory		28,900	(7,578)
Accounts payable		99,933	(90,309)
Taxes accrued		29,429	108,229
Interest accrued		(13,487)	(34,368)
Deferred fuel costs		(159,592)	165,384
Other working capital accounts		(78,553)	(133,142)
Changes in provisions for estimated losses		2,760	55,177
Changes in other regulatory assets		164,716	155,244
Changes in other regulatory liabilities		110,999	(95,327)
Changes in pensions and other postretirement liabilities		(305,200)	(307,638)
Other Noncash Income (Expense)		(259,343)	30,957
Net cash flow provided by operating activities		2,252,395	2,349,645
INVESTING ACTIVITIES
Construction/capital expenditures		(2,003,427)	(1,701,758)
Allowance for equity funds used during construction		48,807	39,428
Payments to Acquire Property, Plant, and Equipment		(949,329)	0
Nuclear fuel purchases		(160,343)	(340,262)
Payments for Nuclear Fuel		(160,343)	(340,262)
NYPA value sharing payment		0	(70,790)
Payments to storm reserve escrow account		(1,203)	(68,956)
Decrease (increase) in other investments		12,374	(15,323)
Proceeds from nuclear decommissioning trust fund sales		1,796,566	1,487,759
Investment in nuclear decommissioning trust funds		(1,844,514)	(1,520,461)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		122,488	0
Proceeds from insurance		0	12,745
Changes in securitization account		(3,911)	(8,756)
Net cash flow used in investing activities		(2,982,492)	(2,186,374)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		5,508,461	2,205,884
Common stock and treasury stock		33,120	24,218
Retirement of long-term debt		(4,229,599)	(2,295,118)
Payments for Repurchase of Common Stock		0	(99,807)
Payments for Repurchase of Preferred Stock and Preference Stock		(85,283)	(94,285)
Changes in credit borrowings and commercial paper - net		(60,985)	183,627
Dividends paid:
Common stock		(455,993)	(447,268)
Preferred stock		(16,947)	(14,848)
Other		(6,204)	(7,102)
Net cash flow provided by (used in) financing activities		686,570	(544,699)
Net decrease in cash and cash equivalents		(43,527)	(381,428)
Cash and cash equivalents at beginning of period		1,350,961	1,422,026
Cash and cash equivalents at end of period		1,307,434	1,040,598
Cash paid / (received) during the period for:
Interest - net of amount capitalized		584,362	523,489
Income taxes		79,988	95,779
System Energy [Member]
OPERATING ACTIVITIES
Consolidated net income (loss)		73,418	72,616
Adjustments to reconcile consolidated net income (loss) to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		176,571	203,761
Deferred income taxes, investment tax credits, and non-current taxes accrued		73,829	181,430
Changes in working capital:
Receivables		9,084	7,800
Accounts payable		(2,217)	(3,480)
Taxes accrued		(30,063)	(159,911)
Interest accrued		406	(17,522)
Other working capital accounts		(22,051)	(2,710)
Changes in other regulatory assets		(12,392)	(4,145)
Changes in pensions and other postretirement liabilities		(15,789)	(17,759)
Other Noncash Income (Expense)		(16,037)	(20,239)
Net cash flow provided by operating activities		234,759	239,841
INVESTING ACTIVITIES
Construction/capital expenditures		(71,471)	(48,756)
Allowance for equity funds used during construction		6,089	5,945
Change in money pool receivable - net		8,415	(1,003)
Nuclear fuel purchases		(137,248)	(51,645)
Payments for Nuclear Fuel		(137,248)	(51,645)
Proceeds from sale of nuclear fuel		11,467	57,681
Proceeds from nuclear decommissioning trust fund sales		392,926	325,367
Investment in nuclear decommissioning trust funds		(419,255)	(348,606)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		15,806	0
Net cash flow used in investing activities		(193,271)	(61,017)
Proceeds from the issuance of:
Retirement of long-term debt		(22,002)	(111,310)
Changes in credit borrowings and commercial paper - net		80,041	(5,836)
Dividends paid:
Common stock		(139,000)	(130,750)
Other		(26)	(28)
Net cash flow provided by (used in) financing activities		(80,987)	(247,924)
Net decrease in cash and cash equivalents		(39,499)	(69,100)
Cash and cash equivalents at beginning of period		230,661	223,179
Cash and cash equivalents at end of period		191,162	154,079
Cash paid / (received) during the period for:
Interest - net of amount capitalized		27,087	47,664
Income taxes		3,402	25,304
Entergy Arkansas [Member]
OPERATING ACTIVITIES
Consolidated net income (loss)		163,333	95,052
Adjustments to reconcile consolidated net income (loss) to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		319,845	303,653
Deferred income taxes, investment tax credits, and non-current taxes accrued		163,202	4,483
Changes in working capital:
Receivables		(116,584)	(74,495)
Fuel inventory		28,968	140
Accounts payable		95,116	16,193
Taxes accrued		(78,879)	34,588
Interest accrued		5,909	4,196
Deferred fuel costs		(50,687)	106,499
Other working capital accounts		4,259	(26,988)
Changes in provisions for estimated losses		130	497
Changes in other regulatory assets		(5,680)	35,483
Changes in pensions and other postretirement liabilities		(77,823)	(97,650)
Other Noncash Income (Expense)		22,691	6,551
Net cash flow provided by operating activities		473,800	408,202
INVESTING ACTIVITIES
Construction/capital expenditures		(494,071)	(428,491)
Allowance for equity funds used during construction		13,134	11,394
Payments to Acquire Property, Plant, and Equipment		(237,324)	0
Change in money pool receivable - net		0	(217)
Nuclear fuel purchases		(80,716)	(119,285)
Payments for Nuclear Fuel		(80,716)	(119,285)
Proceeds from sale of nuclear fuel		40,336	52,281
Proceeds from nuclear decommissioning trust fund sales		165,038	190,759
Investment in nuclear decommissioning trust funds		(176,981)	(197,787)
Changes in securitization account		(3,524)	(4,431)
Other		(102)	0
Net cash flow used in investing activities		(774,210)	(495,777)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		777,671	0
Proceeds from Contributions from Parent		200,000	0
Payments for Repurchase of Redeemable Preferred Stock		85,283	0
Retirement of long-term debt		(621,608)	(6,521)
Change in money pool payable - net		(3,669)	0
Changes in credit borrowings and commercial paper - net		35,717	(10,728)
Dividends paid:
Preferred stock		(6,274)	(5,155)
Other		(1,868)	10,834
Net cash flow provided by (used in) financing activities		294,686	(11,570)
Net decrease in cash and cash equivalents		(5,724)	(99,145)
Cash and cash equivalents at beginning of period		9,135	218,505
Cash and cash equivalents at end of period		3,411	119,360
Cash paid / (received) during the period for:
Interest - net of amount capitalized		78,500	70,902
Income taxes		7,242	17,592
Entergy Louisiana [Member]
OPERATING ACTIVITIES
Consolidated net income (loss)		554,437	422,230
Adjustments to reconcile consolidated net income (loss) to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		462,007	451,967
Deferred income taxes, investment tax credits, and non-current taxes accrued		155,996	4,574
Changes in working capital:
Receivables		(159,517)	(137,129)
Fuel inventory		(1,578)	(650)
Accounts payable		(18,420)	2,500
Taxes accrued		(55,780)	179,275
Interest accrued		7,531	2,227
Deferred fuel costs		(6,091)	(21,311)
Other working capital accounts		(2,503)	(38,176)
Changes in provisions for estimated losses		1,658	(4,747)
Changes in other regulatory assets		73,920	78,809
Changes in pensions and other postretirement liabilities		(63,735)	(52,046)
Other Noncash Income (Expense)		(69,980)	(63,629)
Net cash flow provided by operating activities		877,945	823,894
INVESTING ACTIVITIES
Construction/capital expenditures		(675,248)	(568,812)
Allowance for equity funds used during construction		18,479	15,194
Payments to Acquire Property, Plant, and Equipment		(474,670)	0
Change in money pool receivable - net		(3,274)	(2,919)
Nuclear fuel purchases		(49,219)	(216,721)
Payments for Nuclear Fuel		(49,219)	(216,721)
Proceeds from sale of nuclear fuel		64,498	54,595
Payments to storm reserve escrow account		0	(206)
Decrease (increase) in other investments		(823)	0
Proceeds from Sale of Productive Assets		0	58,417
Proceeds from nuclear decommissioning trust fund sales		178,183	93,580
Investment in nuclear decommissioning trust funds		(206,976)	(118,341)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		17,274	0
Changes in securitization account		(6,649)	(6,837)
Net cash flow used in investing activities		(1,138,425)	(692,050)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		1,389,315	0
Payments for Repurchase of Redeemable Preferred Stock		0	10,284
Retirement of long-term debt		(831,632)	(28,819)
Payments for Repurchase of Preferred Stock and Related Expense		0	100,002
Changes in credit borrowings and commercial paper - net		(18,385)	72,020
Dividends paid:
Common stock		(215,000)	(100,000)
Preferred stock		0	(6,082)
Other		(3,841)	(15,475)
Net cash flow provided by (used in) financing activities		320,457	(188,642)
Net decrease in cash and cash equivalents		59,977	(56,798)
Cash and cash equivalents at beginning of period		35,102	320,516
Cash and cash equivalents at end of period		95,079	263,718
Cash paid / (received) during the period for:
Interest - net of amount capitalized		251,196	186,865
Income taxes		62,676	89,123
Entergy Mississippi [Member]
OPERATING ACTIVITIES
Consolidated net income (loss)		95,924	87,790
Adjustments to reconcile consolidated net income (loss) to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		101,746	95,888
Deferred income taxes, investment tax credits, and non-current taxes accrued		43,201	(9,178)
Changes in working capital:
Receivables		(39,253)	4,628
Fuel inventory		412	(6,627)
Accounts payable		25,200	(14,918)
Taxes accrued		(765)	52,202
Interest accrued		(2,349)	(5,241)
Deferred fuel costs		(79,671)	81,084
Other working capital accounts		(1,910)	(6,528)
Changes in provisions for estimated losses		5,221	(1,670)
Changes in other regulatory assets		18,851	46,016
Changes in pensions and other postretirement liabilities		(18,871)	(22,345)
Other Noncash Income (Expense)		(5,776)	5,154
Net cash flow provided by operating activities		141,960	306,255
INVESTING ACTIVITIES
Construction/capital expenditures		(223,643)	(146,410)
Allowance for equity funds used during construction		4,072	2,094
Change in money pool receivable - net		(24,986)	(3,616)
Proceeds from insurance		0	12,932
Other		(257)	36
Net cash flow used in investing activities		(244,814)	(134,964)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		624,034	0
Retirement of long-term debt		(332,400)	0
Dividends paid:
Common stock		(24,000)	(36,250)
Preferred stock		(2,121)	(2,121)
Other		0	(90)
Net cash flow provided by (used in) financing activities		265,513	(38,461)
Net decrease in cash and cash equivalents		162,659	132,830
Cash and cash equivalents at beginning of period		145,605	61,633
Cash and cash equivalents at end of period		308,264	194,463
Cash paid / (received) during the period for:
Interest - net of amount capitalized		44,209	46,449
Income taxes		3,878	2,597
Entergy New Orleans [Member]
OPERATING ACTIVITIES
Consolidated net income (loss)		46,712	41,351
Adjustments to reconcile consolidated net income (loss) to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		38,719	32,529
Deferred income taxes, investment tax credits, and non-current taxes accrued		132,201	14,620
Changes in working capital:
Receivables		(17,409)	(10,830)
Fuel inventory		(215)	1,295
Accounts payable		7,088	8,585
Taxes accrued		(87,763)	13,604
Interest accrued		1,172	(287)
Deferred fuel costs		(16,671)	4,829
Other working capital accounts		735	(5,362)
Changes in provisions for estimated losses		678	64,479
Changes in other regulatory assets		6,837	(83,437)
Changes in pensions and other postretirement liabilities		(13,673)	(13,999)
Other Noncash Income (Expense)		(5,588)	16,077
Net cash flow provided by operating activities		92,823	83,454
INVESTING ACTIVITIES
Construction/capital expenditures		(63,161)	(64,280)
Allowance for equity funds used during construction		767	1,022
Payments to Acquire Property, Plant, and Equipment		(237,335)	0
Payments to Acquire Businesses and Interest in Affiliates		(38)	0
Change in money pool receivable - net		9,622	(10)
Payments to storm reserve escrow account		(300)	(68,793)
Receipts from storm reserve escrow account		3	6
Changes in securitization account		(502)	(1,434)
Net cash flow used in investing activities		(290,944)	(133,489)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		190,697	95,436
Proceeds from Contributions from Parent		47,750	0
Repayment of long-term payable due to Entergy Louisiana		0	(58,417)
Retirement of long-term debt		(77,094)	0
Dividends paid:
Common stock		(14,000)	(7,250)
Preferred stock		(724)	(724)
Other		505	(126)
Net cash flow provided by (used in) financing activities		147,134	28,919
Net decrease in cash and cash equivalents		(50,987)	(21,116)
Cash and cash equivalents at beginning of period		88,876	42,389
Cash and cash equivalents at end of period		37,889	21,273
Cash paid / (received) during the period for:
Interest - net of amount capitalized		13,613	9,710
Income taxes		8,500	40
Entergy Texas [Member]
OPERATING ACTIVITIES
Consolidated net income (loss)		94,753	74,795
Adjustments to reconcile consolidated net income (loss) to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		79,526	76,356
Deferred income taxes, investment tax credits, and non-current taxes accrued		(7,605)	(50,401)
Changes in working capital:
Receivables		(40,678)	(22,160)
Fuel inventory		268	(3,098)
Accounts payable		(74)	(7,401)
Taxes accrued		55,121	86,361
Interest accrued		(9,453)	(7,172)
Deferred fuel costs		(6,472)	(6,524)
Other working capital accounts		(9,786)	(4,656)
Changes in provisions for estimated losses		(3,318)	(3,878)
Changes in other regulatory assets		69,324	87,314
Changes in pensions and other postretirement liabilities		(21,092)	(22,396)
Other Noncash Income (Expense)		(3,816)	(11,415)
Net cash flow provided by operating activities		196,698	185,725
INVESTING ACTIVITIES
Construction/capital expenditures		(264,394)	(210,595)
Allowance for equity funds used during construction		6,266	3,961
Change in money pool receivable - net		0	224
Changes in securitization account		6,762	3,946
Net cash flow used in investing activities		(251,366)	(202,464)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		123,502	246,617
Retirement of long-term debt		(55,764)	(253,645)
Change in money pool payable - net		(9,669)	0
Dividends paid:
Other		(4,240)	(1,494)
Net cash flow provided by (used in) financing activities		53,829	(8,522)
Net decrease in cash and cash equivalents		(839)	(25,261)
Cash and cash equivalents at beginning of period		2,182	30,441
Cash and cash equivalents at end of period		1,343	5,180
Cash paid / (received) during the period for:
Interest - net of amount capitalized		73,570	69,005
Income taxes		$ 3,443	$ 3,162
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $15.6 million and $9.6 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, 2016	Dec. 31, 2015
Cash and cash equivalents:
Cash	$ 101,905	$ 63,497
Temporary cash investments	1,205,529	1,287,464
Total cash and cash equivalents	1,307,434	1,350,961
Accounts receivable:
Customer	724,970	608,491
Allowance for doubtful accounts	(11,387)	(39,895)
Other	227,278	178,364
Accrued unbilled revenues	439,596	321,940
Total accounts receivable	1,380,457	1,068,900
Deferred fuel costs	41,686	0
Fuel inventory - at average cost	188,910	217,810
Materials and supplies - at average cost	918,269	873,357
Deferred nuclear refueling outage costs	217,487	211,512
Prepayments and other	285,792	344,872
TOTAL	4,340,035	4,067,412
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	717	4,341
Decommissioning trust funds	5,671,074	5,349,953
Non-utility property - at cost (less accumulated depreciation)	223,008	219,999
Other	473,964	468,704
TOTAL	6,368,763	6,042,997
PROPERTY, PLANT, AND EQUIPMENT
Electric	47,486,695	44,467,159
Property under capital lease	609,852	952,465
Natural gas	408,360	392,032
Construction work in progress	1,451,492	1,456,735
Nuclear fuel	1,170,956	1,345,422
TOTAL PROPERTY, PLANT, AND EQUIPMENT	51,127,355	48,613,813
Less - accumulated depreciation and amortization	21,798,230	20,789,452
PROPERTY, PLANT, AND EQUIPMENT - NET	29,329,125	27,824,361
Regulatory assets:
Regulatory asset for income taxes - net	777,113	775,528
Other regulatory assets	4,540,895	4,704,796
Deferred fuel costs	239,050	238,902
Goodwill	377,172	377,172
Accumulated deferred income taxes	123,085	54,903
Other	1,642,943	561,610
TOTAL	7,700,258	6,712,911
TOTAL ASSETS	47,738,181	44,647,681
CURRENT LIABILITIES
Currently maturing long-term debt	750,200	214,374
Notes payable and commercial paper	433,363	494,348
Accounts payable	1,063,139	1,071,798
Customer deposits	402,794	419,407
Taxes Payable, Current	239,506	210,077
Interest accrued	181,078	194,565
Deferred fuel costs	118,228	235,986
Obligations under capital leases	2,743	2,709
Pension and other postretirement liabilities	59,767	62,513
Other	200,929	184,181
TOTAL	3,451,747	3,089,958
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	8,510,946	8,306,865
Accumulated deferred investment tax credits	228,757	234,300
Obligations under capital leases	24,957	27,001
Other regulatory liabilities	1,525,897	1,414,898
Decommissioning and asset retirement cost liabilities	6,101,283	4,790,187
Accumulated provisions	463,466	460,727
Pension and other postretirement liabilities	2,884,903	3,187,357
Long-term debt	13,861,703	13,111,556
Other	382,275	449,856
TOTAL	33,984,187	31,982,747
Subsidiaries' preferred stock without sinking fund	233,185	318,185
Common Shareholders' Equity:
Common stock	2,548	2,548
Paid-in capital	5,403,987	5,403,758
Retained earnings	10,123,086	9,393,913
Accumulated other comprehensive income	38,136	8,951
Less - treasury stock, at cost	5,498,695	5,552,379
TOTAL	10,069,062	9,256,791
TOTAL	10,069,062	9,256,791
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	47,738,181	44,647,681
Entergy Arkansas [Member]
Cash and cash equivalents:
Cash	3,394	9,066
Temporary cash investments	17	69
Total cash and cash equivalents	3,411	9,135
Securitization recovery trust account	7,728	4,204
Accounts receivable:
Customer	149,798	108,636
Allowance for doubtful accounts	(1,605)	(34,226)
Associated companies	30,465	32,987
Other	81,260	84,216
Accrued unbilled revenues	122,884	73,583
Total accounts receivable	382,802	265,196
Deferred fuel costs	41,686	0
Fuel inventory - at average cost	33,721	62,689
Materials and supplies - at average cost	179,018	169,919
Deferred nuclear refueling outage costs	44,291	67,834
Prepaid Taxes	109,170	30,291
Prepayments and other	18,899	15,145
TOTAL	820,726	624,413
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	823,816	771,313
Other	7,914	12,895
TOTAL	831,730	784,208
PROPERTY, PLANT, AND EQUIPMENT
Electric	10,314,236	9,536,802
Property under capital lease	751	844
Construction work in progress	324,877	388,075
Nuclear fuel	245,251	286,341
TOTAL PROPERTY, PLANT, AND EQUIPMENT	10,885,115	10,212,062
Less - accumulated depreciation and amortization	4,578,460	4,349,809
PROPERTY, PLANT, AND EQUIPMENT - NET	6,306,655	5,862,253
Regulatory assets:
Regulatory asset for income taxes - net	71,853	61,438
Other regulatory assets	1,329,038	1,333,773
Deferred fuel costs	66,848	66,700
Other	16,692	14,989
TOTAL	1,484,431	1,476,900
TOTAL ASSETS	9,443,542	8,747,774
CURRENT LIABILITIES
Currently maturing long-term debt	0	55,000
Short-term borrowings	47,408	11,690
Associated companies accounts payable	186,791	110,464
Other	161,929	177,758
Customer deposits	97,046	118,340
Interest accrued	25,792	19,883
Deferred fuel costs	0	8,853
Other	53,654	45,219
TOTAL	572,620	547,207
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	2,153,146	1,982,812
Accumulated deferred investment tax credits	35,605	36,506
Other regulatory liabilities	292,545	242,913
Decommissioning and asset retirement cost liabilities	912,254	872,346
Accumulated provisions	5,682	5,552
Pension and other postretirement liabilities	381,333	459,153
Long-term debt	2,796,059	2,574,839
Other	13,154	18,438
TOTAL	6,589,778	6,192,559
Subsidiaries' preferred stock without sinking fund	31,350	116,350
Common Shareholders' Equity:
Common stock	470	470
Paid-in capital	790,243	588,493
Retained earnings	1,459,081	1,302,695
TOTAL	2,249,794	1,891,658
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	9,443,542	8,747,774
Entergy Louisiana [Member]
Cash and cash equivalents:
Cash	37,460	348
Temporary cash investments	57,619	34,754
Total cash and cash equivalents	95,079	35,102
Accounts receivable:
Customer	253,637	179,051
Allowance for doubtful accounts	(6,656)	(4,209)
Associated companies	127,871	94,418
Other	108,213	56,793
Accrued unbilled revenues	188,797	143,079
Total accounts receivable	671,862	469,132
Fuel inventory - at average cost	49,623	48,045
Materials and supplies - at average cost	313,764	282,688
Deferred nuclear refueling outage costs	29,566	66,984
Prepayments and other	42,887	28,294
TOTAL	1,202,781	930,245
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	1,390,587	1,390,587
Decommissioning trust funds	1,124,821	1,042,293
Non-utility property - at cost (less accumulated depreciation)	209,969	206,293
Storm Reserve Escrow Account	291,245	290,422
Other	28,882	14,776
TOTAL	3,045,504	2,944,371
PROPERTY, PLANT, AND EQUIPMENT
Electric	19,038,635	17,629,077
Property under capital lease	0	341,514
Natural gas	169,241	159,252
Construction work in progress	547,968	420,874
Nuclear fuel	266,085	386,524
TOTAL PROPERTY, PLANT, AND EQUIPMENT	20,021,929	18,937,241
Less - accumulated depreciation and amortization	8,764,536	8,302,774
PROPERTY, PLANT, AND EQUIPMENT - NET	11,257,393	10,634,467
Regulatory assets:
Regulatory asset for income taxes - net	474,622	478,243
Other regulatory assets	1,147,575	1,217,874
Deferred fuel costs	168,122	168,122
Other	16,846	14,125
TOTAL	1,807,165	1,878,364
TOTAL ASSETS	17,312,843	16,387,447
CURRENT LIABILITIES
Currently maturing long-term debt	200,198	29,372
Short-term borrowings	41,971	60,356
Associated companies accounts payable	91,071	165,419
Other	317,672	276,280
Customer deposits	149,293	146,555
Taxes Payable, Current	69,362	125,142
Interest accrued	81,911	74,380
Deferred fuel costs	59,143	65,234
Other	90,792	79,982
TOTAL	1,101,413	1,022,720
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	2,657,512	2,506,956
Accumulated deferred investment tax credits	127,996	131,760
Regulatory liability for income taxes - net	0	2,473
Other regulatory liabilities	849,470	818,623
Decommissioning and asset retirement cost liabilities	1,068,709	1,027,862
Accumulated provisions	311,940	310,282
Pension and other postretirement liabilities	769,240	833,185
Long-term debt	5,207,699	4,806,790
Long-term payables of associated companies	134	1,073
Other	142,728	188,411
TOTAL	11,135,428	10,627,415
Common Shareholders' Equity:
Accumulated other comprehensive income	(57,137)	(56,412)
Members' Equity	5,133,139	4,793,724
TOTAL	5,076,002	4,737,312
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	17,312,843	16,387,447
Entergy Mississippi [Member]
Cash and cash equivalents:
Cash	961	1,426
Temporary cash investments	307,303	144,179
Total cash and cash equivalents	308,264	145,605
Accounts receivable:
Customer	56,699	56,685
Allowance for doubtful accounts	(687)	(718)
Associated companies	85,361	34,964
Other	8,328	8,276
Accrued unbilled revenues	61,029	47,284
Total accounts receivable	210,730	146,491
Fuel inventory - at average cost	50,861	51,273
Materials and supplies - at average cost	40,396	39,491
Prepayments and other	8,380	5,184
TOTAL	618,631	388,044
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,612	4,625
Escrow accounts	31,816	41,726
TOTAL	36,428	46,351
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,223,311	4,083,933
Property under capital lease	1,936	2,942
Construction work in progress	137,717	114,067
TOTAL PROPERTY, PLANT, AND EQUIPMENT	4,362,964	4,200,942
Less - accumulated depreciation and amortization	1,582,162	1,534,522
PROPERTY, PLANT, AND EQUIPMENT - NET	2,780,802	2,666,420
Regulatory assets:
Regulatory asset for income taxes - net	39,243	45,790
Other regulatory assets	318,777	328,681
Other	2,920	2,121
TOTAL	360,940	376,592
TOTAL ASSETS	3,796,801	3,477,407
CURRENT LIABILITIES
Currently maturing long-term debt	0	125,000
Associated companies accounts payable	37,869	38,496
Other	70,443	51,502
Customer deposits	83,479	81,583
Taxes Payable, Current	42,696	43,461
Interest accrued	18,482	20,831
Deferred fuel costs	28,083	107,754
Other	12,906	22,754
TOTAL	293,958	491,381
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	840,514	810,635
Accumulated deferred investment tax credits	7,441	4,645
Decommissioning and asset retirement cost liabilities	8,602	8,252
Accumulated provisions	53,283	48,062
Pension and other postretirement liabilities	101,338	120,217
Long-term debt	1,344,305	920,085
Other	15,126	11,699
TOTAL	2,370,609	1,923,595
Subsidiaries' preferred stock without sinking fund	50,381	50,381
Common Shareholders' Equity:
Common stock	199,326	199,326
Paid-in capital	(690)	(690)
Retained earnings	883,217	813,414
TOTAL	1,081,853	1,012,050
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	3,796,801	3,477,407
Entergy New Orleans [Member]
Cash and cash equivalents:
Cash	644	1,068
Temporary cash investments	37,245	87,808
Total cash and cash equivalents	37,889	88,876
Securitization recovery trust account	5,122	4,620
Accounts receivable:
Customer	51,467	34,627
Allowance for doubtful accounts	(1,499)	(268)
Associated companies	10,043	23,248
Other	4,180	3,753
Accrued unbilled revenues	22,755	17,799
Total accounts receivable	86,946	79,159
Fuel inventory - at average cost	2,127	1,912
Materials and supplies - at average cost	8,993	13,244
Prepaid Taxes	90,457	2,694
Prepayments and other	10,877	7,569
TOTAL	242,411	198,074
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	1,016	1,016
Storm Reserve Escrow Account	81,299	81,002
Other	7,160	3
TOTAL	89,475	82,021
PROPERTY, PLANT, AND EQUIPMENT
Electric	1,251,039	1,051,239
Natural gas	239,118	232,780
Construction work in progress	24,863	29,027
TOTAL PROPERTY, PLANT, AND EQUIPMENT	1,515,020	1,313,046
Less - accumulated depreciation and amortization	606,343	648,081
PROPERTY, PLANT, AND EQUIPMENT - NET	908,677	664,965
Regulatory assets:
Other regulatory assets	258,485	265,322
Deferred fuel costs	4,080	4,080
Other	931	682
TOTAL	263,496	270,084
TOTAL ASSETS	1,504,059	1,215,144
CURRENT LIABILITIES
Current payable due Entergy Louisiana	4,973	4,973
Associated companies accounts payable	39,066	37,467
Other	26,419	21,471
Customer deposits	28,507	28,392
Interest accrued	6,081	4,909
Deferred fuel costs	12,350	29,021
Other	13,012	6,216
TOTAL	130,408	132,449
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	327,389	214,061
Accumulated deferred investment tax credits	655	753
Regulatory liability for income taxes - net	9,231	13,199
Decommissioning and asset retirement cost liabilities	2,827	2,687
Accumulated provisions	84,865	84,187
Pension and other postretirement liabilities	29,936	43,609
Long-term debt	433,795	317,380
Gas system rebuild insurance proceeds	3,904	12,788
Long-term payable due to Entergy Louisiana	20,527	20,527
Other	10,972	3,692
TOTAL	924,101	712,883
Subsidiaries' preferred stock without sinking fund	19,780	19,780
Common Shareholders' Equity:
Common stock	33,744	33,744
Paid-in capital	171,544	123,794
Retained earnings	224,482	192,494
TOTAL	429,770	350,032
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	1,504,059	1,215,144
Entergy Texas [Member]
Cash and cash equivalents:
Cash	1,314	2,153
Temporary cash investments	29	29
Total cash and cash equivalents	1,343	2,182
Securitization recovery trust account	31,399	38,161
Accounts receivable:
Customer	86,623	61,870
Allowance for doubtful accounts	(939)	(474)
Associated companies	51,390	42,279
Other	14,397	11,054
Accrued unbilled revenues	44,131	40,195
Total accounts receivable	195,602	154,924
Fuel inventory - at average cost	46,674	46,942
Materials and supplies - at average cost	37,725	34,994
Prepayments and other	25,342	17,975
TOTAL	338,085	295,178
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	599	620
Non-utility property - at cost (less accumulated depreciation)	376	376
Other	20,907	20,186
TOTAL	21,882	21,182
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,218,696	3,923,100
Construction work in progress	139,189	210,964
TOTAL PROPERTY, PLANT, AND EQUIPMENT	4,357,885	4,134,064
Less - accumulated depreciation and amortization	1,544,349	1,477,529
PROPERTY, PLANT, AND EQUIPMENT - NET	2,813,536	2,656,535
Regulatory assets:
Regulatory asset for income taxes - net	107,349	107,499
Other regulatory assets	743,688	812,862
Other	4,608	5,326
TOTAL	855,645	925,687
TOTAL ASSETS	4,029,148	3,898,582
CURRENT LIABILITIES
Associated companies accounts payable	65,675	106,065
Other	93,026	87,421
Customer deposits	44,469	44,537
Taxes Payable, Current	60,454	5,333
Interest accrued	19,753	29,206
Deferred fuel costs	18,652	25,124
Other	10,712	10,363
TOTAL	312,741	308,049
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	998,037	1,006,834
Accumulated deferred investment tax credits	13,159	13,835
Other regulatory liabilities	7,106	6,396
Decommissioning and asset retirement cost liabilities	6,381	6,124
Accumulated provisions	6,001	9,319
Pension and other postretirement liabilities	56,456	77,517
Long-term debt	1,521,270	1,451,967
Other	51,788	57,085
TOTAL	2,660,198	2,629,077
Common Shareholders' Equity:
Common stock	49,452	49,452
Paid-in capital	481,994	481,994
Retained earnings	524,763	430,010
TOTAL	1,056,209	961,456
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	4,029,148	3,898,582
System Energy [Member]
Cash and cash equivalents:
Cash	988	8,681
Temporary cash investments	190,174	221,980
Total cash and cash equivalents	191,162	230,661
Accounts receivable:
Associated companies	79,582	93,724
Other	1,217	4,574
Total accounts receivable	80,799	98,298
Materials and supplies - at average cost	82,334	87,366
Deferred nuclear refueling outage costs	29,840	5,605
Prepaid Taxes	39,390	9,327
Prepayments and other	4,801	1,955
TOTAL	428,326	433,212
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	764,903	701,460
TOTAL	764,903	701,460
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,315,805	4,253,949
Property under capital lease	575,027	575,027
Construction work in progress	63,010	92,546
Nuclear fuel	258,363	183,706
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,212,205	5,105,228
Less - accumulated depreciation and amortization	3,039,533	2,961,842
PROPERTY, PLANT, AND EQUIPMENT - NET	2,172,672	2,143,386
Regulatory assets:
Regulatory asset for income taxes - net	93,277	98,230
Other regulatory assets	365,175	347,830
Other	4,921	4,757
TOTAL	463,373	450,817
TOTAL ASSETS	3,829,274	3,728,875
CURRENT LIABILITIES
Currently maturing long-term debt	50,003	2
Short-term borrowings	80,041	0
Associated companies accounts payable	7,328	7,391
Other	24,736	34,010
Interest accrued	14,589	14,183
Other	1,928	1,926
TOTAL	178,625	57,512
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	1,088,503	1,019,075
Accumulated deferred investment tax credits	42,652	45,451
Other regulatory liabilities	365,302	337,424
Decommissioning and asset retirement cost liabilities	841,187	803,405
Pension and other postretirement liabilities	96,475	112,264
Long-term debt	501,020	572,665
Other	13	0
TOTAL	2,935,152	2,890,284
Common Shareholders' Equity:
Common stock	679,350	719,350
Retained earnings	36,147	61,729
TOTAL	715,497	781,079
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$ 3,829,274	$ 3,728,875

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Securitization property	$ 627,347	$ 714,044
Securitization bonds	$ 697,535	$ 774,696
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	75,625,184	76,363,763
Entergy Arkansas [Member]
Securitization property	$ 44,320	$ 54,450
Securitization bonds	$ 54,884	$ 61,249
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	$ 97,805	$ 114,701
Securitization bonds	$ 110,783	$ 120,549
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	$ 84,345	$ 91,599
Securitization bonds	$ 90,147	$ 95,867
Common stock, par value	$ 4	$ 4
Common stock, shares authorized	10,000,000	10,000,000
Common stock, shares issued	8,435,900	8,435,900
Common stock, shares outstanding	8,435,900	8,435,900
Entergy Texas [Member]
Securitization property	$ 400,875	$ 453,317
Securitization bonds	$ 441,721	$ 497,030
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]Preferred Membership Interest	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]Paid In Capital [Member]	Entergy New Orleans [Member]Retained Earnings [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]
Beginning Balance at Dec. 31, 2014	$ 10,101,725		$ 94,000		$ 5,375,353	$ 10,169,657		$ (42,307)	$ 2,548	$ (5,497,526)	$ 1,824,237	$ 588,471	$ 1,235,296	$ 470	$ 4,346,987	$ 110,000	$ 4,316,210	$ (79,223)	$ 962,170	$ (690)	$ 763,534	$ 199,326	$ 228,025	$ 36,294	$ 157,987	$ 33,744	$ 891,831	$ 481,994	$ 360,385	$ 49,452	$ 870,511	$ 81,161	$ 789,350
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Consolidated net income (loss)	(261,583)	[1]	14,552	[1]	0	(276,135)	[1]	0	0	0	95,052	0	95,052	0	422,230	0	422,230	0	87,790	0	87,790	0	41,351	0	41,351	0	74,795	0	74,795	0	72,616	72,616	0
Net income attributable to Entergy Louisiana																							(2,203)	0	(2,203)	0
Other comprehensive income (loss)	(75,491)		0		0	0		(75,491)	0	0					1,204	0	0	1,204
Preferred Stock Redemptions	94,285		94,000		0	285		0	0	0					110,000	110,000	0	0
Payments for Repurchase of Common Stock	(99,807)		0		0	0		0	0	(99,807)
Payments for Repurchase of Preferred Stock and Preference Stock	(94,285)
Common stock issuances related to stock plans	48,386		0		3,594	0		0	0	44,792
Common stock dividends declared	(447,268)		0		0	(447,268)		0	0	0					(100,000)	0	(100,000)	0	(36,250)	0	(36,250)	0	(7,250)	0	(7,250)	0					(130,750)	(130,750)	0
Proceeds from Contributions from Parent											0												0
Preferred dividend requirements of subsidiaries	(14,552)	[1]	(14,552)	[1]	0	0		0	0	0	(5,155)	0	(5,155)	0	(5,737)	0	(5,737)	0	(2,121)	0	(2,121)	0	(724)	0	(724)	0
Other															(313)	0	(313)	0
Ending Balance at Sep. 30, 2015	9,157,125		0		5,378,947	9,445,969		(117,798)	2,548	(5,552,541)	1,914,134	588,471	1,325,193	470	4,554,371	0	4,632,390	(78,019)	1,011,589	(690)	812,953	199,326	259,199	36,294	189,161	33,744	966,626	481,994	435,180	49,452	812,377	23,027	789,350
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Payments for Repurchase of Preferred Stock and Related Expense															100,002
Beginning Balance at Dec. 31, 2015	9,256,791		0		5,403,758	9,393,913		8,951	2,548	(5,552,379)	1,891,658	588,493	1,302,695	470	4,737,312	0	4,793,724	(56,412)	1,012,050	(690)	813,414	199,326	350,032	123,794	192,494	33,744	961,456	481,994	430,010	49,452	781,079	61,729	719,350
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Consolidated net income (loss)	1,201,035	[1]	15,586	[1]	0	1,185,449	[1]	0	0	0	163,333	0	163,333	0	554,437	0	554,437	0	95,924	0	95,924	0	46,712	0	46,712	0	94,753	0	94,753	0	73,418	73,418	0
Other comprehensive income (loss)	29,185		0		0	0		29,185	0	0					(725)	0	0	(725)
Preferred Stock Redemptions	283		0		0	283		0	0	0	284	1,750	2,034	0
Payments for Repurchase of Common Stock	0
Payments for Repurchase of Preferred Stock and Preference Stock	(85,283)
Common stock issuances related to stock plans	53,913		0		229	0		0	0	53,684
Common stock dividends declared	(455,993)		0		0	(455,993)		0	0	0					(215,000)	0	(215,000)	0	(24,000)	0	(24,000)	0	(14,000)	0	(14,000)	0					(139,000)	(99,000)	(40,000)
Proceeds from Contributions from Parent											200,000	200,000	0	0									47,750	47,750	0	0
Preferred dividend requirements of subsidiaries	(15,586)	[1]	(15,586)	[1]	0	0		0	0	0	(4,913)	0	(4,913)	0					(2,121)	0	(2,121)	0	(724)	0	(724)	0
Other															(22)	0	(22)	0
Ending Balance at Sep. 30, 2016	$ 10,069,062		$ 0		$ 5,403,987	$ 10,123,086		$ 38,136	$ 2,548	$ (5,498,695)	$ 2,249,794	$ 790,243	$ 1,459,081	$ 470	5,076,002	$ 0	$ 5,133,139	$ (57,137)	$ 1,081,853	$ (690)	$ 883,217	$ 199,326	$ 429,770	$ 171,544	$ 224,482	$ 33,744	$ 1,056,209	$ 481,994	$ 524,763	$ 49,452	$ 715,497	$ 36,147	$ 679,350
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Payments for Repurchase of Preferred Stock and Related Expense															$ 0
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $15.6 million and $9.6 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Consolidated Statements Of Cha7

Consolidated Statements Of Changes In Equity (Parenthetical) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Statement of Stockholders' Equity [Abstract]
Preferred dividends on subsidiaries' preferred stock	$ 15.6	$ 9.6

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016		Sep. 30, 2015
Net income	$ 393,204	$ (718,233)	$ 1,201,035	[1]	$ (261,583)	[1]
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss)	20,972	(23,984)	(52,575)		(14,618)
Pension and other postretirement liabilities	5,044	7,437	17,649		23,323
Net unrealized investment gains	21,367	(53,966)	65,391		(83,843)
Foreign currency translation	(92)	(469)	(1,280)		(353)
Other comprehensive income (loss)	47,291	(70,982)	29,185		(75,491)
Total comprehensive income	440,495	(789,215)	1,230,220		(337,074)
Preferred dividend requirements of subsidiaries	5,034	4,794	15,586	[1]	14,552	[1]
Comprehensive Income Attributable to Entergy Corporation	435,461	(794,009)	1,214,634		(351,626)
Entergy Louisiana [Member]
Net income	189,506	187,140	554,437		422,230
Other comprehensive income (loss)
Pension and other postretirement liabilities	(232)	412	(725)		1,204
Other comprehensive income (loss)	(232)	412	(725)		1,204
Total comprehensive income	$ 189,274	$ 187,552	$ 553,712		423,434
Preferred dividend requirements of subsidiaries					$ 5,737
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $15.6 million and $9.6 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Consolidated Statements Of Com9

Consolidated Statements Of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Cash flow hedges net unrealized gain (loss), tax expense (benefit)	$ 11,172	$ (13,010)	$ (28,605)	$ (8,202)
Pension and other postretirement liabilities, tax expense	4,064	4,166	7,101	11,506
Net unrealized investment gains, tax expense	20,635	(51,295)	58,508	(77,921)
Foreign currency translation, tax expense	(48)	(253)	(688)	(190)
Entergy Louisiana [Member]
Pension and other postretirement liabilities, tax expense	$ (145)	$ 258	$ (404)	$ 803

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2016
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. 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 and subsequent NRC reviews. As discussed in the Form 10-K, in March 2015 the NRC issued a letter notifying Entergy of its decision to move ANO into the “multiple/repetitive degraded cornerstone column” (Column 4) of the NRC’s Reactor Oversight Process Action Matrix. Placement into Column 4 requires significant additional NRC inspection activities at the ANO site, including a review of the site’s root cause evaluation associated with the flood barrier and stator issues, an assessment of the effectiveness of the site’s corrective action program, an additional design basis inspection, a safety culture assessment, and possibly other inspection activities consistent with the NRC’s Inspection Procedure. Entergy Arkansas incurred incremental expenses of approximately $53 million in 2015 to prepare for the NRC inspection that began in early 2016. Excluding remediation and response costs that may result from the additional NRC inspection activities, Entergy Arkansas expects to incur incremental expenses of approximately $50 million in 2016, of which $37 million was incurred as of September 30, 2016, in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. A lesser amount of incremental expenses is expected to be ongoing annually after 2016, until ANO transitions out of Column 4. The NRC completed the supplemental inspection required for ANO’s Column 4 designation in February 2016, and published its inspection report in June 2016. In its inspection report, the NRC concluded that the ANO site is being operated safely and that Entergy understands the depth and breadth of performance concerns associated with ANO’s performance decline. Also in June 2016, the NRC issued a confirmatory action letter to confirm the actions Entergy Arkansas has taken and will continue to take to improve performance at ANO. The NRC will verify the completion of those actions through quarterly follow-up inspections, the results of which will determine when ANO should transition out of Column 4. Pilgrim NRC Oversight and Planned Shutdown In September 2015 the NRC placed Pilgrim in its “multiple/repetitive degraded cornerstone column” (Column 4) of its Reactor Oversight Process Action Matrix due to its finding of continuing weaknesses in Pilgrim’s corrective action program that contributed to repeated unscheduled shutdowns and equipment failures. The preliminary estimate of direct costs of Pilgrim’s response to a planned NRC enhanced inspection ranges from $45 million to $60 million in operation and maintenance expense, including approximately $30 million in 2016, of which $20 million was incurred as of September 30, 2016. The estimate does not include potential capital investment or other costs to address issues that may arise in the inspection. Entergy determined in April 2016 that it intends to refuel Pilgrim in 2017 and then cease operations May 31, 2019. In October 2015, Entergy previously announced its intention to cease operations at Pilgrim because of poor market conditions, reduced revenues, and increased operational costs. Pilgrim currently has approximately 677 MW of Capacity Supply Obligations in ISO New England through May 2019. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the current Presidential administration’s defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Management cannot predict the potential timing or magnitude of future spent fuel fee revisions that may occur. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2016 related to Entergy’s nuclear owner licensee subsidiaries litigation with the DOE. In December 2015 the U.S. Court of Federal Claims issued a judgment in the amount of $81 million in favor of Entergy Nuclear Indian Point 3 and Entergy Nuclear FitzPatrick in the first round Indian Point 3/FitzPatrick damages case, and Entergy received the payment from the U.S. Treasury in June 2016. The effect of recording the Indian Point 3 proceeds was a reduction to plant, other operation and maintenance expense, and depreciation expense. The Indian Point 3 damages award included $45 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $45 million, Entergy recorded $8 million as a reduction to previously-recorded depreciation expense. Entergy reduced its Indian Point 3 plant asset balance by the remaining $37 million . The effect of recording the FitzPatrick proceeds was a reduction to plant and other operation and maintenance expense. The FitzPatrick damages awarded included $32 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $32 million, Entergy recorded an $11 million reduction to bring its remaining FitzPatrick plant asset balance to zero . The remaining $21 million was recorded as a reduction to other operation and maintenance expense because FitzPatrick’s plant asset balance is fully impaired. In April 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $42 million in favor of Entergy Louisiana and against the DOE in the first round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in August 2016. The effects of recording the final judgment in the third quarter 2016 were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The River Bend damages awarded included $17 million related to costs previously capitalized, $23 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $17 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its River Bend plant asset balance by the remaining $14 million . In September 2016 the U.S. Court of Federal Claims issued a further judgment in the River Bend case in the amount of $5 million . In May 2016, Entergy Nuclear Vermont Yankee and the DOE entered into a stipulation agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $19 million in favor of Entergy Nuclear Vermont Yankee and against the DOE in the second round Vermont Yankee damages case. Entergy received payment from the U.S. Treasury in June 2016. The effect of recording the proceeds was a reduction to other operation and maintenance expense and depreciation expense. The damages awarded included $15 million related to costs previously capitalized and $4 million related to costs previously recorded as other operation and maintenance expense. Of the $15 million, Entergy recorded $2 million as a reduction to previously-recorded depreciation expense. The remaining $13 million would have been recorded as a reduction to Vermont Yankee’s plant asset balance, but was recorded as a reduction to other operation and maintenance expense because Vermont Yankee’s plant asset balance is fully impaired. In June 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $49 million in favor of System Energy and against the DOE in the second round Grand Gulf damages case. System Energy received payment from the U.S. Treasury in August 2016. The effects of recording the judgment in the third quarter 2016 were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The amounts of Grand Gulf damages awarded related to System Energy’s 90% ownership of Grand Gulf included $16 million related to costs previously capitalized, $19 million related to costs previously recorded as nuclear fuel expense, and $9 million related to costs previously recorded as other operation and maintenance expense. Of the $16 million, System Energy recorded $4 million as a reduction to previously-recorded depreciation expense. System Energy reduced its Grand Gulf plant asset balance by the remaining $12 million . In July 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $31 million in favor of Entergy Arkansas and against the DOE in the second round ANO damages case. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Arkansas requested payment from the U.S. Treasury of the $31 million in September 2016 and recorded a receivable as of September 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The ANO damages award included $6 million related to costs previously capitalized, $19 million related to costs previously recorded as nuclear fuel expense, and $6 million related to costs previously recorded as other operation and maintenance expense. Entergy Arkansas reduced its ANO plant asset balance by the $6 million . In August 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $53 million in favor of Entergy Louisiana and against the DOE in the first round Waterford 3 damages case. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Louisiana requested payment from the U.S. Treasury of the $53 million in September 2016 and recorded a receivable as of September 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The Waterford 3 damages award included $41 million related to costs previously capitalized, $10 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $41 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its Waterford 3 plant asset balance by the remaining $38 million . In September 2016 the U.S. Supreme Court of Federal Claims issued a judgment in the Entergy Nuclear Palisades case in the amount of $14 million . The Court previously issued a partial judgment in the case in the amount of $21 million , which was paid by the U.S. Treasury in October 2015. The appeals period for the judgment has not yet expired. In October 2016 the U.S. Supreme Court of Federal Claims issued a judgment in the second round Entergy Nuclear Indian Point 2 case in the amount of $34 million . The appeals period for the judgment has not yet expired. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance 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. Conventional 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 Litigation 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 Louisiana and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation at Entergy Louisiana and Entergy Texas.
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. 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 and subsequent NRC reviews. As discussed in the Form 10-K, in March 2015 the NRC issued a letter notifying Entergy of its decision to move ANO into the “multiple/repetitive degraded cornerstone column” (Column 4) of the NRC’s Reactor Oversight Process Action Matrix. Placement into Column 4 requires significant additional NRC inspection activities at the ANO site, including a review of the site’s root cause evaluation associated with the flood barrier and stator issues, an assessment of the effectiveness of the site’s corrective action program, an additional design basis inspection, a safety culture assessment, and possibly other inspection activities consistent with the NRC’s Inspection Procedure. Entergy Arkansas incurred incremental expenses of approximately $53 million in 2015 to prepare for the NRC inspection that began in early 2016. Excluding remediation and response costs that may result from the additional NRC inspection activities, Entergy Arkansas expects to incur incremental expenses of approximately $50 million in 2016, of which $37 million was incurred as of September 30, 2016, in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. A lesser amount of incremental expenses is expected to be ongoing annually after 2016, until ANO transitions out of Column 4. The NRC completed the supplemental inspection required for ANO’s Column 4 designation in February 2016, and published its inspection report in June 2016. In its inspection report, the NRC concluded that the ANO site is being operated safely and that Entergy understands the depth and breadth of performance concerns associated with ANO’s performance decline. Also in June 2016, the NRC issued a confirmatory action letter to confirm the actions Entergy Arkansas has taken and will continue to take to improve performance at ANO. The NRC will verify the completion of those actions through quarterly follow-up inspections, the results of which will determine when ANO should transition out of Column 4. Pilgrim NRC Oversight and Planned Shutdown In September 2015 the NRC placed Pilgrim in its “multiple/repetitive degraded cornerstone column” (Column 4) of its Reactor Oversight Process Action Matrix due to its finding of continuing weaknesses in Pilgrim’s corrective action program that contributed to repeated unscheduled shutdowns and equipment failures. The preliminary estimate of direct costs of Pilgrim’s response to a planned NRC enhanced inspection ranges from $45 million to $60 million in operation and maintenance expense, including approximately $30 million in 2016, of which $20 million was incurred as of September 30, 2016. The estimate does not include potential capital investment or other costs to address issues that may arise in the inspection. Entergy determined in April 2016 that it intends to refuel Pilgrim in 2017 and then cease operations May 31, 2019. In October 2015, Entergy previously announced its intention to cease operations at Pilgrim because of poor market conditions, reduced revenues, and increased operational costs. Pilgrim currently has approximately 677 MW of Capacity Supply Obligations in ISO New England through May 2019. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the current Presidential administration’s defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Management cannot predict the potential timing or magnitude of future spent fuel fee revisions that may occur. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2016 related to Entergy’s nuclear owner licensee subsidiaries litigation with the DOE. In December 2015 the U.S. Court of Federal Claims issued a judgment in the amount of $81 million in favor of Entergy Nuclear Indian Point 3 and Entergy Nuclear FitzPatrick in the first round Indian Point 3/FitzPatrick damages case, and Entergy received the payment from the U.S. Treasury in June 2016. The effect of recording the Indian Point 3 proceeds was a reduction to plant, other operation and maintenance expense, and depreciation expense. The Indian Point 3 damages award included $45 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $45 million, Entergy recorded $8 million as a reduction to previously-recorded depreciation expense. Entergy reduced its Indian Point 3 plant asset balance by the remaining $37 million . The effect of recording the FitzPatrick proceeds was a reduction to plant and other operation and maintenance expense. The FitzPatrick damages awarded included $32 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $32 million, Entergy recorded an $11 million reduction to bring its remaining FitzPatrick plant asset balance to zero . The remaining $21 million was recorded as a reduction to other operation and maintenance expense because FitzPatrick’s plant asset balance is fully impaired. In April 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $42 million in favor of Entergy Louisiana and against the DOE in the first round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in August 2016. The effects of recording the final judgment in the third quarter 2016 were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The River Bend damages awarded included $17 million related to costs previously capitalized, $23 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $17 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its River Bend plant asset balance by the remaining $14 million . In September 2016 the U.S. Court of Federal Claims issued a further judgment in the River Bend case in the amount of $5 million . In May 2016, Entergy Nuclear Vermont Yankee and the DOE entered into a stipulation agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $19 million in favor of Entergy Nuclear Vermont Yankee and against the DOE in the second round Vermont Yankee damages case. Entergy received payment from the U.S. Treasury in June 2016. The effect of recording the proceeds was a reduction to other operation and maintenance expense and depreciation expense. The damages awarded included $15 million related to costs previously capitalized and $4 million related to costs previously recorded as other operation and maintenance expense. Of the $15 million, Entergy recorded $2 million as a reduction to previously-recorded depreciation expense. The remaining $13 million would have been recorded as a reduction to Vermont Yankee’s plant asset balance, but was recorded as a reduction to other operation and maintenance expense because Vermont Yankee’s plant asset balance is fully impaired. In June 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $49 million in favor of System Energy and against the DOE in the second round Grand Gulf damages case. System Energy received payment from the U.S. Treasury in August 2016. The effects of recording the judgment in the third quarter 2016 were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The amounts of Grand Gulf damages awarded related to System Energy’s 90% ownership of Grand Gulf included $16 million related to costs previously capitalized, $19 million related to costs previously recorded as nuclear fuel expense, and $9 million related to costs previously recorded as other operation and maintenance expense. Of the $16 million, System Energy recorded $4 million as a reduction to previously-recorded depreciation expense. System Energy reduced its Grand Gulf plant asset balance by the remaining $12 million . In July 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $31 million in favor of Entergy Arkansas and against the DOE in the second round ANO damages case. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Arkansas requested payment from the U.S. Treasury of the $31 million in September 2016 and recorded a receivable as of September 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The ANO damages award included $6 million related to costs previously capitalized, $19 million related to costs previously recorded as nuclear fuel expense, and $6 million related to costs previously recorded as other operation and maintenance expense. Entergy Arkansas reduced its ANO plant asset balance by the $6 million . In August 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $53 million in favor of Entergy Louisiana and against the DOE in the first round Waterford 3 damages case. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Louisiana requested payment from the U.S. Treasury of the $53 million in September 2016 and recorded a receivable as of September 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The Waterford 3 damages award included $41 million related to costs previously capitalized, $10 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $41 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its Waterford 3 plant asset balance by the remaining $38 million . In September 2016 the U.S. Supreme Court of Federal Claims issued a judgment in the Entergy Nuclear Palisades case in the amount of $14 million . The Court previously issued a partial judgment in the case in the amount of $21 million , which was paid by the U.S. Treasury in October 2015. The appeals period for the judgment has not yet expired. In October 2016 the U.S. Supreme Court of Federal Claims issued a judgment in the second round Entergy Nuclear Indian Point 2 case in the amount of $34 million . The appeals period for the judgment has not yet expired. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance 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. Conventional 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 Litigation 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 Louisiana and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation at Entergy Louisiana and Entergy Texas.
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. 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 and subsequent NRC reviews. As discussed in the Form 10-K, in March 2015 the NRC issued a letter notifying Entergy of its decision to move ANO into the “multiple/repetitive degraded cornerstone column” (Column 4) of the NRC’s Reactor Oversight Process Action Matrix. Placement into Column 4 requires significant additional NRC inspection activities at the ANO site, including a review of the site’s root cause evaluation associated with the flood barrier and stator issues, an assessment of the effectiveness of the site’s corrective action program, an additional design basis inspection, a safety culture assessment, and possibly other inspection activities consistent with the NRC’s Inspection Procedure. Entergy Arkansas incurred incremental expenses of approximately $53 million in 2015 to prepare for the NRC inspection that began in early 2016. Excluding remediation and response costs that may result from the additional NRC inspection activities, Entergy Arkansas expects to incur incremental expenses of approximately $50 million in 2016, of which $37 million was incurred as of September 30, 2016, in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. A lesser amount of incremental expenses is expected to be ongoing annually after 2016, until ANO transitions out of Column 4. The NRC completed the supplemental inspection required for ANO’s Column 4 designation in February 2016, and published its inspection report in June 2016. In its inspection report, the NRC concluded that the ANO site is being operated safely and that Entergy understands the depth and breadth of performance concerns associated with ANO’s performance decline. Also in June 2016, the NRC issued a confirmatory action letter to confirm the actions Entergy Arkansas has taken and will continue to take to improve performance at ANO. The NRC will verify the completion of those actions through quarterly follow-up inspections, the results of which will determine when ANO should transition out of Column 4. Pilgrim NRC Oversight and Planned Shutdown In September 2015 the NRC placed Pilgrim in its “multiple/repetitive degraded cornerstone column” (Column 4) of its Reactor Oversight Process Action Matrix due to its finding of continuing weaknesses in Pilgrim’s corrective action program that contributed to repeated unscheduled shutdowns and equipment failures. The preliminary estimate of direct costs of Pilgrim’s response to a planned NRC enhanced inspection ranges from $45 million to $60 million in operation and maintenance expense, including approximately $30 million in 2016, of which $20 million was incurred as of September 30, 2016. The estimate does not include potential capital investment or other costs to address issues that may arise in the inspection. Entergy determined in April 2016 that it intends to refuel Pilgrim in 2017 and then cease operations May 31, 2019. In October 2015, Entergy previously announced its intention to cease operations at Pilgrim because of poor market conditions, reduced revenues, and increased operational costs. Pilgrim currently has approximately 677 MW of Capacity Supply Obligations in ISO New England through May 2019. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the current Presidential administration’s defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Management cannot predict the potential timing or magnitude of future spent fuel fee revisions that may occur. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2016 related to Entergy’s nuclear owner licensee subsidiaries litigation with the DOE. In December 2015 the U.S. Court of Federal Claims issued a judgment in the amount of $81 million in favor of Entergy Nuclear Indian Point 3 and Entergy Nuclear FitzPatrick in the first round Indian Point 3/FitzPatrick damages case, and Entergy received the payment from the U.S. Treasury in June 2016. The effect of recording the Indian Point 3 proceeds was a reduction to plant, other operation and maintenance expense, and depreciation expense. The Indian Point 3 damages award included $45 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $45 million, Entergy recorded $8 million as a reduction to previously-recorded depreciation expense. Entergy reduced its Indian Point 3 plant asset balance by the remaining $37 million . The effect of recording the FitzPatrick proceeds was a reduction to plant and other operation and maintenance expense. The FitzPatrick damages awarded included $32 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $32 million, Entergy recorded an $11 million reduction to bring its remaining FitzPatrick plant asset balance to zero . The remaining $21 million was recorded as a reduction to other operation and maintenance expense because FitzPatrick’s plant asset balance is fully impaired. In April 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $42 million in favor of Entergy Louisiana and against the DOE in the first round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in August 2016. The effects of recording the final judgment in the third quarter 2016 were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The River Bend damages awarded included $17 million related to costs previously capitalized, $23 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $17 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its River Bend plant asset balance by the remaining $14 million . In September 2016 the U.S. Court of Federal Claims issued a further judgment in the River Bend case in the amount of $5 million . In May 2016, Entergy Nuclear Vermont Yankee and the DOE entered into a stipulation agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $19 million in favor of Entergy Nuclear Vermont Yankee and against the DOE in the second round Vermont Yankee damages case. Entergy received payment from the U.S. Treasury in June 2016. The effect of recording the proceeds was a reduction to other operation and maintenance expense and depreciation expense. The damages awarded included $15 million related to costs previously capitalized and $4 million related to costs previously recorded as other operation and maintenance expense. Of the $15 million, Entergy recorded $2 million as a reduction to previously-recorded depreciation expense. The remaining $13 million would have been recorded as a reduction to Vermont Yankee’s plant asset balance, but was recorded as a reduction to other operation and maintenance expense because Vermont Yankee’s plant asset balance is fully impaired. In June 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $49 million in favor of System Energy and against the DOE in the second round Grand Gulf damages case. System Energy received payment from the U.S. Treasury in August 2016. The effects of recording the judgment in the third quarter 2016 were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The amounts of Grand Gulf damages awarded related to System Energy’s 90% ownership of Grand Gulf included $16 million related to costs previously capitalized, $19 million related to costs previously recorded as nuclear fuel expense, and $9 million related to costs previously recorded as other operation and maintenance expense. Of the $16 million, System Energy recorded $4 million as a reduction to previously-recorded depreciation expense. System Energy reduced its Grand Gulf plant asset balance by the remaining $12 million . In July 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $31 million in favor of Entergy Arkansas and against the DOE in the second round ANO damages case. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Arkansas requested payment from the U.S. Treasury of the $31 million in September 2016 and recorded a receivable as of September 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The ANO damages award included $6 million related to costs previously capitalized, $19 million related to costs previously recorded as nuclear fuel expense, and $6 million related to costs previously recorded as other operation and maintenance expense. Entergy Arkansas reduced its ANO plant asset balance by the $6 million . In August 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $53 million in favor of Entergy Louisiana and against the DOE in the first round Waterford 3 damages case. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Louisiana requested payment from the U.S. Treasury of the $53 million in September 2016 and recorded a receivable as of September 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The Waterford 3 damages award included $41 million related to costs previously capitalized, $10 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $41 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its Waterford 3 plant asset balance by the remaining $38 million . In September 2016 the U.S. Supreme Court of Federal Claims issued a judgment in the Entergy Nuclear Palisades case in the amount of $14 million . The Court previously issued a partial judgment in the case in the amount of $21 million , which was paid by the U.S. Treasury in October 2015. The appeals period for the judgment has not yet expired. In October 2016 the U.S. Supreme Court of Federal Claims issued a judgment in the second round Entergy Nuclear Indian Point 2 case in the amount of $34 million . The appeals period for the judgment has not yet expired. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance 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. Conventional 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 Litigation 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 Louisiana and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation at Entergy Louisiana and Entergy Texas.
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. 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 and subsequent NRC reviews. As discussed in the Form 10-K, in March 2015 the NRC issued a letter notifying Entergy of its decision to move ANO into the “multiple/repetitive degraded cornerstone column” (Column 4) of the NRC’s Reactor Oversight Process Action Matrix. Placement into Column 4 requires significant additional NRC inspection activities at the ANO site, including a review of the site’s root cause evaluation associated with the flood barrier and stator issues, an assessment of the effectiveness of the site’s corrective action program, an additional design basis inspection, a safety culture assessment, and possibly other inspection activities consistent with the NRC’s Inspection Procedure. Entergy Arkansas incurred incremental expenses of approximately $53 million in 2015 to prepare for the NRC inspection that began in early 2016. Excluding remediation and response costs that may result from the additional NRC inspection activities, Entergy Arkansas expects to incur incremental expenses of approximately $50 million in 2016, of which $37 million was incurred as of September 30, 2016, in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. A lesser amount of incremental expenses is expected to be ongoing annually after 2016, until ANO transitions out of Column 4. The NRC completed the supplemental inspection required for ANO’s Column 4 designation in February 2016, and published its inspection report in June 2016. In its inspection report, the NRC concluded that the ANO site is being operated safely and that Entergy understands the depth and breadth of performance concerns associated with ANO’s performance decline. Also in June 2016, the NRC issued a confirmatory action letter to confirm the actions Entergy Arkansas has taken and will continue to take to improve performance at ANO. The NRC will verify the completion of those actions through quarterly follow-up inspections, the results of which will determine when ANO should transition out of Column 4. Pilgrim NRC Oversight and Planned Shutdown In September 2015 the NRC placed Pilgrim in its “multiple/repetitive degraded cornerstone column” (Column 4) of its Reactor Oversight Process Action Matrix due to its finding of continuing weaknesses in Pilgrim’s corrective action program that contributed to repeated unscheduled shutdowns and equipment failures. The preliminary estimate of direct costs of Pilgrim’s response to a planned NRC enhanced inspection ranges from $45 million to $60 million in operation and maintenance expense, including approximately $30 million in 2016, of which $20 million was incurred as of September 30, 2016. The estimate does not include potential capital investment or other costs to address issues that may arise in the inspection. Entergy determined in April 2016 that it intends to refuel Pilgrim in 2017 and then cease operations May 31, 2019. In October 2015, Entergy previously announced its intention to cease operations at Pilgrim because of poor market conditions, reduced revenues, and increased operational costs. Pilgrim currently has approximately 677 MW of Capacity Supply Obligations in ISO New England through May 2019. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the current Presidential administration’s defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Management cannot predict the potential timing or magnitude of future spent fuel fee revisions that may occur. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2016 related to Entergy’s nuclear owner licensee subsidiaries litigation with the DOE. In December 2015 the U.S. Court of Federal Claims issued a judgment in the amount of $81 million in favor of Entergy Nuclear Indian Point 3 and Entergy Nuclear FitzPatrick in the first round Indian Point 3/FitzPatrick damages case, and Entergy received the payment from the U.S. Treasury in June 2016. The effect of recording the Indian Point 3 proceeds was a reduction to plant, other operation and maintenance expense, and depreciation expense. The Indian Point 3 damages award included $45 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $45 million, Entergy recorded $8 million as a reduction to previously-recorded depreciation expense. Entergy reduced its Indian Point 3 plant asset balance by the remaining $37 million . The effect of recording the FitzPatrick proceeds was a reduction to plant and other operation and maintenance expense. The FitzPatrick damages awarded included $32 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $32 million, Entergy recorded an $11 million reduction to bring its remaining FitzPatrick plant asset balance to zero . The remaining $21 million was recorded as a reduction to other operation and maintenance expense because FitzPatrick’s plant asset balance is fully impaired. In April 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $42 million in favor of Entergy Louisiana and against the DOE in the first round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in August 2016. The effects of recording the final judgment in the third quarter 2016 were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The River Bend damages awarded included $17 million related to costs previously capitalized, $23 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $17 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its River Bend plant asset balance by the remaining $14 million . In September 2016 the U.S. Court of Federal Claims issued a further judgment in the River Bend case in the amount of $5 million . In May 2016, Entergy Nuclear Vermont Yankee and the DOE entered into a stipulation agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $19 million in favor of Entergy Nuclear Vermont Yankee and against the DOE in the second round Vermont Yankee damages case. Entergy received payment from the U.S. Treasury in June 2016. The effect of recording the proceeds was a reduction to other operation and maintenance expense and depreciation expense. The damages awarded included $15 million related to costs previously capitalized and $4 million related to costs previously recorded as other operation and maintenance expense. Of the $15 million, Entergy recorded $2 million as a reduction to previously-recorded depreciation expense. The remaining $13 million would have been recorded as a reduction to Vermont Yankee’s plant asset balance, but was recorded as a reduction to other operation and maintenance expense because Vermont Yankee’s plant asset balance is fully impaired. In June 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $49 million in favor of System Energy and against the DOE in the second round Grand Gulf damages case. System Energy received payment from the U.S. Treasury in August 2016. The effects of recording the judgment in the third quarter 2016 were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The amounts of Grand Gulf damages awarded related to System Energy’s 90% ownership of Grand Gulf included $16 million related to costs previously capitalized, $19 million related to costs previously recorded as nuclear fuel expense, and $9 million related to costs previously recorded as other operation and maintenance expense. Of the $16 million, System Energy recorded $4 million as a reduction to previously-recorded depreciation expense. System Energy reduced its Grand Gulf plant asset balance by the remaining $12 million . In July 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $31 million in favor of Entergy Arkansas and against the DOE in the second round ANO damages case. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Arkansas requested payment from the U.S. Treasury of the $31 million in September 2016 and recorded a receivable as of September 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The ANO damages award included $6 million related to costs previously capitalized, $19 million related to costs previously recorded as nuclear fuel expense, and $6 million related to costs previously recorded as other operation and maintenance expense. Entergy Arkansas reduced its ANO plant asset balance by the $6 million . In August 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $53 million in favor of Entergy Louisiana and against the DOE in the first round Waterford 3 damages case. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Louisiana requested payment from the U.S. Treasury of the $53 million in September 2016 and recorded a receivable as of September 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The Waterford 3 damages award included $41 million related to costs previously capitalized, $10 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $41 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its Waterford 3 plant asset balance by the remaining $38 million . In September 2016 the U.S. Supreme Court of Federal Claims issued a judgment in the Entergy Nuclear Palisades case in the amount of $14 million . The Court previously issued a partial judgment in the case in the amount of $21 million , which was paid by the U.S. Treasury in October 2015. The appeals period for the judgment has not yet expired. In October 2016 the U.S. Supreme Court of Federal Claims issued a judgment in the second round Entergy Nuclear Indian Point 2 case in the amount of $34 million . The appeals period for the judgment has not yet expired. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance 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. Conventional 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 Litigation 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 Louisiana and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation at Entergy Louisiana and Entergy Texas.
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. 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 and subsequent NRC reviews. As discussed in the Form 10-K, in March 2015 the NRC issued a letter notifying Entergy of its decision to move ANO into the “multiple/repetitive degraded cornerstone column” (Column 4) of the NRC’s Reactor Oversight Process Action Matrix. Placement into Column 4 requires significant additional NRC inspection activities at the ANO site, including a review of the site’s root cause evaluation associated with the flood barrier and stator issues, an assessment of the effectiveness of the site’s corrective action program, an additional design basis inspection, a safety culture assessment, and possibly other inspection activities consistent with the NRC’s Inspection Procedure. Entergy Arkansas incurred incremental expenses of approximately $53 million in 2015 to prepare for the NRC inspection that began in early 2016. Excluding remediation and response costs that may result from the additional NRC inspection activities, Entergy Arkansas expects to incur incremental expenses of approximately $50 million in 2016, of which $37 million was incurred as of September 30, 2016, in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. A lesser amount of incremental expenses is expected to be ongoing annually after 2016, until ANO transitions out of Column 4. The NRC completed the supplemental inspection required for ANO’s Column 4 designation in February 2016, and published its inspection report in June 2016. In its inspection report, the NRC concluded that the ANO site is being operated safely and that Entergy understands the depth and breadth of performance concerns associated with ANO’s performance decline. Also in June 2016, the NRC issued a confirmatory action letter to confirm the actions Entergy Arkansas has taken and will continue to take to improve performance at ANO. The NRC will verify the completion of those actions through quarterly follow-up inspections, the results of which will determine when ANO should transition out of Column 4. Pilgrim NRC Oversight and Planned Shutdown In September 2015 the NRC placed Pilgrim in its “multiple/repetitive degraded cornerstone column” (Column 4) of its Reactor Oversight Process Action Matrix due to its finding of continuing weaknesses in Pilgrim’s corrective action program that contributed to repeated unscheduled shutdowns and equipment failures. The preliminary estimate of direct costs of Pilgrim’s response to a planned NRC enhanced inspection ranges from $45 million to $60 million in operation and maintenance expense, including approximately $30 million in 2016, of which $20 million was incurred as of September 30, 2016. The estimate does not include potential capital investment or other costs to address issues that may arise in the inspection. Entergy determined in April 2016 that it intends to refuel Pilgrim in 2017 and then cease operations May 31, 2019. In October 2015, Entergy previously announced its intention to cease operations at Pilgrim because of poor market conditions, reduced revenues, and increased operational costs. Pilgrim currently has approximately 677 MW of Capacity Supply Obligations in ISO New England through May 2019. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the current Presidential administration’s defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Management cannot predict the potential timing or magnitude of future spent fuel fee revisions that may occur. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2016 related to Entergy’s nuclear owner licensee subsidiaries litigation with the DOE. In December 2015 the U.S. Court of Federal Claims issued a judgment in the amount of $81 million in favor of Entergy Nuclear Indian Point 3 and Entergy Nuclear FitzPatrick in the first round Indian Point 3/FitzPatrick damages case, and Entergy received the payment from the U.S. Treasury in June 2016. The effect of recording the Indian Point 3 proceeds was a reduction to plant, other operation and maintenance expense, and depreciation expense. The Indian Point 3 damages award included $45 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $45 million, Entergy recorded $8 million as a reduction to previously-recorded depreciation expense. Entergy reduced its Indian Point 3 plant asset balance by the remaining $37 million . The effect of recording the FitzPatrick proceeds was a reduction to plant and other operation and maintenance expense. The FitzPatrick damages awarded included $32 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $32 million, Entergy recorded an $11 million reduction to bring its remaining FitzPatrick plant asset balance to zero . The remaining $21 million was recorded as a reduction to other operation and maintenance expense because FitzPatrick’s plant asset balance is fully impaired. In April 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $42 million in favor of Entergy Louisiana and against the DOE in the first round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in August 2016. The effects of recording the final judgment in the third quarter 2016 were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The River Bend damages awarded included $17 million related to costs previously capitalized, $23 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $17 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its River Bend plant asset balance by the remaining $14 million . In September 2016 the U.S. Court of Federal Claims issued a further judgment in the River Bend case in the amount of $5 million . In May 2016, Entergy Nuclear Vermont Yankee and the DOE entered into a stipulation agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $19 million in favor of Entergy Nuclear Vermont Yankee and against the DOE in the second round Vermont Yankee damages case. Entergy received payment from the U.S. Treasury in June 2016. The effect of recording the proceeds was a reduction to other operation and maintenance expense and depreciation expense. The damages awarded included $15 million related to costs previously capitalized and $4 million related to costs previously recorded as other operation and maintenance expense. Of the $15 million, Entergy recorded $2 million as a reduction to previously-recorded depreciation expense. The remaining $13 million would have been recorded as a reduction to Vermont Yankee’s plant asset balance, but was recorded as a reduction to other operation and maintenance expense because Vermont Yankee’s plant asset balance is fully impaired. In June 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $49 million in favor of System Energy and against the DOE in the second round Grand Gulf damages case. System Energy received payment from the U.S. Treasury in August 2016. The effects of recording the judgment in the third quarter 2016 were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The amounts of Grand Gulf damages awarded related to System Energy’s 90% ownership of Grand Gulf included $16 million related to costs previously capitalized, $19 million related to costs previously recorded as nuclear fuel expense, and $9 million related to costs previously recorded as other operation and maintenance expense. Of the $16 million, System Energy recorded $4 million as a reduction to previously-recorded depreciation expense. System Energy reduced its Grand Gulf plant asset balance by the remaining $12 million . In July 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $31 million in favor of Entergy Arkansas and against the DOE in the second round ANO damages case. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Arkansas requested payment from the U.S. Treasury of the $31 million in September 2016 and recorded a receivable as of September 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The ANO damages award included $6 million related to costs previously capitalized, $19 million related to costs previously recorded as nuclear fuel expense, and $6 million related to costs previously recorded as other operation and maintenance expense. Entergy Arkansas reduced its ANO plant asset balance by the $6 million . In August 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $53 million in favor of Entergy Louisiana and against the DOE in the first round Waterford 3 damages case. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Louisiana requested payment from the U.S. Treasury of the $53 million in September 2016 and recorded a receivable as of September 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The Waterford 3 damages award included $41 million related to costs previously capitalized, $10 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $41 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its Waterford 3 plant asset balance by the remaining $38 million . In September 2016 the U.S. Supreme Court of Federal Claims issued a judgment in the Entergy Nuclear Palisades case in the amount of $14 million . The Court previously issued a partial judgment in the case in the amount of $21 million , which was paid by the U.S. Treasury in October 2015. The appeals period for the judgment has not yet expired. In October 2016 the U.S. Supreme Court of Federal Claims issued a judgment in the second round Entergy Nuclear Indian Point 2 case in the amount of $34 million . The appeals period for the judgment has not yet expired. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance 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. Conventional 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 Litigation 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 Louisiana and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation at Entergy Louisiana and Entergy Texas.
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. 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 and subsequent NRC reviews. As discussed in the Form 10-K, in March 2015 the NRC issued a letter notifying Entergy of its decision to move ANO into the “multiple/repetitive degraded cornerstone column” (Column 4) of the NRC’s Reactor Oversight Process Action Matrix. Placement into Column 4 requires significant additional NRC inspection activities at the ANO site, including a review of the site’s root cause evaluation associated with the flood barrier and stator issues, an assessment of the effectiveness of the site’s corrective action program, an additional design basis inspection, a safety culture assessment, and possibly other inspection activities consistent with the NRC’s Inspection Procedure. Entergy Arkansas incurred incremental expenses of approximately $53 million in 2015 to prepare for the NRC inspection that began in early 2016. Excluding remediation and response costs that may result from the additional NRC inspection activities, Entergy Arkansas expects to incur incremental expenses of approximately $50 million in 2016, of which $37 million was incurred as of September 30, 2016, in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. A lesser amount of incremental expenses is expected to be ongoing annually after 2016, until ANO transitions out of Column 4. The NRC completed the supplemental inspection required for ANO’s Column 4 designation in February 2016, and published its inspection report in June 2016. In its inspection report, the NRC concluded that the ANO site is being operated safely and that Entergy understands the depth and breadth of performance concerns associated with ANO’s performance decline. Also in June 2016, the NRC issued a confirmatory action letter to confirm the actions Entergy Arkansas has taken and will continue to take to improve performance at ANO. The NRC will verify the completion of those actions through quarterly follow-up inspections, the results of which will determine when ANO should transition out of Column 4. Pilgrim NRC Oversight and Planned Shutdown In September 2015 the NRC placed Pilgrim in its “multiple/repetitive degraded cornerstone column” (Column 4) of its Reactor Oversight Process Action Matrix due to its finding of continuing weaknesses in Pilgrim’s corrective action program that contributed to repeated unscheduled shutdowns and equipment failures. The preliminary estimate of direct costs of Pilgrim’s response to a planned NRC enhanced inspection ranges from $45 million to $60 million in operation and maintenance expense, including approximately $30 million in 2016, of which $20 million was incurred as of September 30, 2016. The estimate does not include potential capital investment or other costs to address issues that may arise in the inspection. Entergy determined in April 2016 that it intends to refuel Pilgrim in 2017 and then cease operations May 31, 2019. In October 2015, Entergy previously announced its intention to cease operations at Pilgrim because of poor market conditions, reduced revenues, and increased operational costs. Pilgrim currently has approximately 677 MW of Capacity Supply Obligations in ISO New England through May 2019. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the current Presidential administration’s defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Management cannot predict the potential timing or magnitude of future spent fuel fee revisions that may occur. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2016 related to Entergy’s nuclear owner licensee subsidiaries litigation with the DOE. In December 2015 the U.S. Court of Federal Claims issued a judgment in the amount of $81 million in favor of Entergy Nuclear Indian Point 3 and Entergy Nuclear FitzPatrick in the first round Indian Point 3/FitzPatrick damages case, and Entergy received the payment from the U.S. Treasury in June 2016. The effect of recording the Indian Point 3 proceeds was a reduction to plant, other operation and maintenance expense, and depreciation expense. The Indian Point 3 damages award included $45 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $45 million, Entergy recorded $8 million as a reduction to previously-recorded depreciation expense. Entergy reduced its Indian Point 3 plant asset balance by the remaining $37 million . The effect of recording the FitzPatrick proceeds was a reduction to plant and other operation and maintenance expense. The FitzPatrick damages awarded included $32 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $32 million, Entergy recorded an $11 million reduction to bring its remaining FitzPatrick plant asset balance to zero . The remaining $21 million was recorded as a reduction to other operation and maintenance expense because FitzPatrick’s plant asset balance is fully impaired. In April 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $42 million in favor of Entergy Louisiana and against the DOE in the first round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in August 2016. The effects of recording the final judgment in the third quarter 2016 were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The River Bend damages awarded included $17 million related to costs previously capitalized, $23 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $17 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its River Bend plant asset balance by the remaining $14 million . In September 2016 the U.S. Court of Federal Claims issued a further judgment in the River Bend case in the amount of $5 million . In May 2016, Entergy Nuclear Vermont Yankee and the DOE entered into a stipulation agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $19 million in favor of Entergy Nuclear Vermont Yankee and against the DOE in the second round Vermont Yankee damages case. Entergy received payment from the U.S. Treasury in June 2016. The effect of recording the proceeds was a reduction to other operation and maintenance expense and depreciation expense. The damages awarded included $15 million related to costs previously capitalized and $4 million related to costs previously recorded as other operation and maintenance expense. Of the $15 million, Entergy recorded $2 million as a reduction to previously-recorded depreciation expense. The remaining $13 million would have been recorded as a reduction to Vermont Yankee’s plant asset balance, but was recorded as a reduction to other operation and maintenance expense because Vermont Yankee’s plant asset balance is fully impaired. In June 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $49 million in favor of System Energy and against the DOE in the second round Grand Gulf damages case. System Energy received payment from the U.S. Treasury in August 2016. The effects of recording the judgment in the third quarter 2016 were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The amounts of Grand Gulf damages awarded related to System Energy’s 90% ownership of Grand Gulf included $16 million related to costs previously capitalized, $19 million related to costs previously recorded as nuclear fuel expense, and $9 million related to costs previously recorded as other operation and maintenance expense. Of the $16 million, System Energy recorded $4 million as a reduction to previously-recorded depreciation expense. System Energy reduced its Grand Gulf plant asset balance by the remaining $12 million . In July 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $31 million in favor of Entergy Arkansas and against the DOE in the second round ANO damages case. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Arkansas requested payment from the U.S. Treasury of the $31 million in September 2016 and recorded a receivable as of September 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The ANO damages award included $6 million related to costs previously capitalized, $19 million related to costs previously recorded as nuclear fuel expense, and $6 million related to costs previously recorded as other operation and maintenance expense. Entergy Arkansas reduced its ANO plant asset balance by the $6 million . In August 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $53 million in favor of Entergy Louisiana and against the DOE in the first round Waterford 3 damages case. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Louisiana requested payment from the U.S. Treasury of the $53 million in September 2016 and recorded a receivable as of September 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The Waterford 3 damages award included $41 million related to costs previously capitalized, $10 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $41 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its Waterford 3 plant asset balance by the remaining $38 million . In September 2016 the U.S. Supreme Court of Federal Claims issued a judgment in the Entergy Nuclear Palisades case in the amount of $14 million . The Court previously issued a partial judgment in the case in the amount of $21 million , which was paid by the U.S. Treasury in October 2015. The appeals period for the judgment has not yet expired. In October 2016 the U.S. Supreme Court of Federal Claims issued a judgment in the second round Entergy Nuclear Indian Point 2 case in the amount of $34 million . The appeals period for the judgment has not yet expired. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance 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. Conventional 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 Litigation 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 Louisiana and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation at Entergy Louisiana and Entergy Texas.
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. 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 and subsequent NRC reviews. As discussed in the Form 10-K, in March 2015 the NRC issued a letter notifying Entergy of its decision to move ANO into the “multiple/repetitive degraded cornerstone column” (Column 4) of the NRC’s Reactor Oversight Process Action Matrix. Placement into Column 4 requires significant additional NRC inspection activities at the ANO site, including a review of the site’s root cause evaluation associated with the flood barrier and stator issues, an assessment of the effectiveness of the site’s corrective action program, an additional design basis inspection, a safety culture assessment, and possibly other inspection activities consistent with the NRC’s Inspection Procedure. Entergy Arkansas incurred incremental expenses of approximately $53 million in 2015 to prepare for the NRC inspection that began in early 2016. Excluding remediation and response costs that may result from the additional NRC inspection activities, Entergy Arkansas expects to incur incremental expenses of approximately $50 million in 2016, of which $37 million was incurred as of September 30, 2016, in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. A lesser amount of incremental expenses is expected to be ongoing annually after 2016, until ANO transitions out of Column 4. The NRC completed the supplemental inspection required for ANO’s Column 4 designation in February 2016, and published its inspection report in June 2016. In its inspection report, the NRC concluded that the ANO site is being operated safely and that Entergy understands the depth and breadth of performance concerns associated with ANO’s performance decline. Also in June 2016, the NRC issued a confirmatory action letter to confirm the actions Entergy Arkansas has taken and will continue to take to improve performance at ANO. The NRC will verify the completion of those actions through quarterly follow-up inspections, the results of which will determine when ANO should transition out of Column 4. Pilgrim NRC Oversight and Planned Shutdown In September 2015 the NRC placed Pilgrim in its “multiple/repetitive degraded cornerstone column” (Column 4) of its Reactor Oversight Process Action Matrix due to its finding of continuing weaknesses in Pilgrim’s corrective action program that contributed to repeated unscheduled shutdowns and equipment failures. The preliminary estimate of direct costs of Pilgrim’s response to a planned NRC enhanced inspection ranges from $45 million to $60 million in operation and maintenance expense, including approximately $30 million in 2016, of which $20 million was incurred as of September 30, 2016. The estimate does not include potential capital investment or other costs to address issues that may arise in the inspection. Entergy determined in April 2016 that it intends to refuel Pilgrim in 2017 and then cease operations May 31, 2019. In October 2015, Entergy previously announced its intention to cease operations at Pilgrim because of poor market conditions, reduced revenues, and increased operational costs. Pilgrim currently has approximately 677 MW of Capacity Supply Obligations in ISO New England through May 2019. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the current Presidential administration’s defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Management cannot predict the potential timing or magnitude of future spent fuel fee revisions that may occur. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2016 related to Entergy’s nuclear owner licensee subsidiaries litigation with the DOE. In December 2015 the U.S. Court of Federal Claims issued a judgment in the amount of $81 million in favor of Entergy Nuclear Indian Point 3 and Entergy Nuclear FitzPatrick in the first round Indian Point 3/FitzPatrick damages case, and Entergy received the payment from the U.S. Treasury in June 2016. The effect of recording the Indian Point 3 proceeds was a reduction to plant, other operation and maintenance expense, and depreciation expense. The Indian Point 3 damages award included $45 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $45 million, Entergy recorded $8 million as a reduction to previously-recorded depreciation expense. Entergy reduced its Indian Point 3 plant asset balance by the remaining $37 million . The effect of recording the FitzPatrick proceeds was a reduction to plant and other operation and maintenance expense. The FitzPatrick damages awarded included $32 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $32 million, Entergy recorded an $11 million reduction to bring its remaining FitzPatrick plant asset balance to zero . The remaining $21 million was recorded as a reduction to other operation and maintenance expense because FitzPatrick’s plant asset balance is fully impaired. In April 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $42 million in favor of Entergy Louisiana and against the DOE in the first round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in August 2016. The effects of recording the final judgment in the third quarter 2016 were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The River Bend damages awarded included $17 million related to costs previously capitalized, $23 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $17 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its River Bend plant asset balance by the remaining $14 million . In September 2016 the U.S. Court of Federal Claims issued a further judgment in the River Bend case in the amount of $5 million . In May 2016, Entergy Nuclear Vermont Yankee and the DOE entered into a stipulation agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $19 million in favor of Entergy Nuclear Vermont Yankee and against the DOE in the second round Vermont Yankee damages case. Entergy received payment from the U.S. Treasury in June 2016. The effect of recording the proceeds was a reduction to other operation and maintenance expense and depreciation expense. The damages awarded included $15 million related to costs previously capitalized and $4 million related to costs previously recorded as other operation and maintenance expense. Of the $15 million, Entergy recorded $2 million as a reduction to previously-recorded depreciation expense. The remaining $13 million would have been recorded as a reduction to Vermont Yankee’s plant asset balance, but was recorded as a reduction to other operation and maintenance expense because Vermont Yankee’s plant asset balance is fully impaired. In June 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $49 million in favor of System Energy and against the DOE in the second round Grand Gulf damages case. System Energy received payment from the U.S. Treasury in August 2016. The effects of recording the judgment in the third quarter 2016 were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The amounts of Grand Gulf damages awarded related to System Energy’s 90% ownership of Grand Gulf included $16 million related to costs previously capitalized, $19 million related to costs previously recorded as nuclear fuel expense, and $9 million related to costs previously recorded as other operation and maintenance expense. Of the $16 million, System Energy recorded $4 million as a reduction to previously-recorded depreciation expense. System Energy reduced its Grand Gulf plant asset balance by the remaining $12 million . In July 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $31 million in favor of Entergy Arkansas and against the DOE in the second round ANO damages case. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Arkansas requested payment from the U.S. Treasury of the $31 million in September 2016 and recorded a receivable as of September 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The ANO damages award included $6 million related to costs previously capitalized, $19 million related to costs previously recorded as nuclear fuel expense, and $6 million related to costs previously recorded as other operation and maintenance expense. Entergy Arkansas reduced its ANO plant asset balance by the $6 million . In August 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $53 million in favor of Entergy Louisiana and against the DOE in the first round Waterford 3 damages case. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Louisiana requested payment from the U.S. Treasury of the $53 million in September 2016 and recorded a receivable as of September 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The Waterford 3 damages award included $41 million related to costs previously capitalized, $10 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $41 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its Waterford 3 plant asset balance by the remaining $38 million . In September 2016 the U.S. Supreme Court of Federal Claims issued a judgment in the Entergy Nuclear Palisades case in the amount of $14 million . The Court previously issued a partial judgment in the case in the amount of $21 million , which was paid by the U.S. Treasury in October 2015. The appeals period for the judgment has not yet expired. In October 2016 the U.S. Supreme Court of Federal Claims issued a judgment in the second round Entergy Nuclear Indian Point 2 case in the amount of $34 million . The appeals period for the judgment has not yet expired. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance 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. Conventional 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 Litigation 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 Louisiana and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation at Entergy Louisiana and Entergy Texas.

Rate And Regulatory Matters

Rate And Regulatory Matters	9 Months Ended
	Sep. 30, 2016
Public Utilities Disclosure [Text Block]	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2016, Entergy Arkansas filed its annual rate redetermination pursuant to the production cost allocation rider, which reflected recovery of the production cost allocation rider true-up adjustment of the 2014 and 2015 unrecovered retail balance in the amount of $1.9 million . Additionally, the redetermined rates reflected the recovery of a $1.9 million System Agreement bandwidth remedy payment resulting from a compliance filing pursuant to the FERC’s December 2015 order related to test year 2009 production costs. The rates for the 2016 production cost allocation rider update became effective with the first billing cycle of July 2016, and rates will be effective through June 2017. Entergy Louisiana In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. The LPSC staff issued its audit report in January 2013. The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million , plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates. The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing. Two parties intervened in the proceeding. A procedural schedule was established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC staff report and any issues raised by intervenors. One intervenor sought further proceedings regarding certain issues it raised in its comments on the LPSC staff report. Entergy Louisiana filed responses to both the LPSC staff report and the issues raised by the intervenor. After conducting additional discovery, in April 2016 the LPSC staff consultant issued its supplemental audit report, which concluded that Entergy Louisiana was not imprudent on the issues raised by the intervenor. The intervenor has stated that it does not intend to pursue these issues further. In October 2016 the LPSC staff filed testimony affirming the recommendation in its audit report that nuclear dry fuel storage costs should be realigned to base rates. A procedural schedule has been established for this proceeding, including an evidentiary hearing in November 2016. In December 2011 the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through 2009. In March 2016 the LPSC staff consultant issued its audit report. In its report, the LPSC staff consultant recommended that Entergy Louisiana refund approximately $8.6 million , plus interest, to customers and realign the recovery of approximately $12.7 million from Entergy Gulf States Louisiana’s fuel adjustment clause to base rates. In September 2016 the LPSC staff filed testimony stating that is was no longer recommending a disallowance of $3.4 million of the $8.6 million discussed above, but otherwise maintained positions from its report. Entergy Louisiana has recorded a provision for the estimated outcome of this proceeding. A procedural schedule has been established for this proceeding, including a hearing in December 2016. In June 2016 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. In recognition of the business combination that occurred in 2015, the audit notice was issued to Entergy Louisiana and will also include a review of charges to legacy Entergy Gulf States Louisiana customers prior to the business combination. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment and purchased gas adjustment mechanisms for the period from 2012 through 2015. Discovery has not commenced. Entergy Mississippi Entergy Mississippi had a deferred fuel over-recovery balance of $58.3 million as of May 31, 2015, along with an under-recovery balance of $12.3 million under the power management rider. Pursuant to those tariffs, in July 2015, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider to flow through to customers the approximately $46 million net over-recovery over a six-month period. In August 2015 the MPSC approved the interim adjustments effective with September 2015 bills. In November 2015, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included a projected over-recovery balance of $48 million projected through January 31, 2016. In January 2016 the MPSC approved the redetermined annual factor effective February 1, 2016. The MPSC further ordered, however, that due to the significant change in natural gas price forecasts since Entergy Mississippi’s filing in November 2015, Entergy Mississippi shall file a revised fuel factor with the MPSC no later than February 1, 2016. Pursuant to that order, Entergy Mississippi submitted a revised fuel factor. Additionally, because Entergy Mississippi’s projected over-recovery balance for the period ending January 31, 2017 was $68 million , in February 2016, Entergy Mississippi filed for another interim adjustment to the energy cost factor effective April 2016 to flow through to customers the projected over-recovery balance over a six-month period. That interim adjustment was approved by the MPSC in February 2016 effective for April 2016 bills. Mississippi Attorney General Complaint 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 complaint is wide ranging and relates to tariffs and procedures under which Entergy Mississippi purchases power not generated in Mississippi to meet electricity demand. Entergy believes the complaint is unfounded. In December 2008 the defendant Entergy companies removed the Attorney General’s lawsuit to U.S. District Court in Jackson, Mississippi. The Mississippi attorney general moved to remand the matter to state court. In August 2012 the District Court issued an opinion denying the Attorney General’s motion for remand, finding that the District Court has subject matter jurisdiction under the Class Action Fairness Act. The defendant Entergy companies answered the complaint and filed a counterclaim for relief based upon the Mississippi Public Utilities Act and the Federal Power Act. In May 2009 the defendant Entergy companies filed a motion for judgment on the pleadings asserting grounds of federal preemption, the exclusive jurisdiction of the MPSC, and factual errors in the Attorney General’s complaint. In September 2012 the District Court heard oral argument on Entergy’s motion for judgment on the pleadings. In January 2014 the U.S. Supreme Court issued a decision in which it held that cases brought by attorneys general as the sole plaintiff to enforce state laws were not considered “mass actions” under the Class Action Fairness Act, so as to establish federal subject matter jurisdiction. One day later the Attorney General renewed his motion to remand the Entergy case back to state court, citing the U.S. Supreme Court’s decision. The defendant Entergy companies responded to that motion reiterating the additional grounds asserted for federal question jurisdiction, and the District Court held oral argument on the renewed motion to remand in February 2014. In April 2015 the District Court entered an order denying the renewed motion to remand, holding that the District Court has federal question subject matter jurisdiction. The Attorney General appealed to the U.S. Fifth Circuit Court of Appeals the denial of the motion to remand. In July 2015 the Fifth Circuit issued an order denying the appeal, and the Attorney General subsequently filed a petition for rehearing of the request for interlocutory appeal, which was also denied. In December 2015 the District Court ordered that the parties submit to the court undisputed and disputed facts that are material to the Entergy defendants’ motion for judgment on the pleadings, as well as supplemental briefs regarding the same. Those filings were made in January 2016. In September 2016 the Attorney General filed a mandamus petition with the U.S. Fifth Circuit Court of Appeals in which the Attorney General asked the Fifth Circuit to order the chief judge to reassign this case to another judge. The District Court denied the Entergy companies’ motion for judgment on the pleadings. The Entergy companies filed a motion seeking to amend the District Court’s order denying the Entergy companies’ motion for judgment on the pleadings and allowing an interlocutory appeal. The Fifth Circuit granted the Attorney General’s motion for writ of mandamus and directed the chief judge to assign the case to a new judge. The case has now been reassigned, and the Entergy companies’ motion to amend the order remains pending. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in the open 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 $10.9 million in 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. Both appeals are pending, but the appeals do not stay the PUCT’s decision. The federal appeal is scheduled to be heard in December 2016. In April 2016, Entergy Texas filed with the PUCT an application to refund to customers approximately $56.2 million . The refund resulted from (i) $41.8 million of fuel cost recovery over-collections through February 2016, (ii) the $10.9 million in bandwidth remedy payments, discussed above, that Entergy Texas received related to calendar year 2006 production costs, and (iii) $3.5 million in bandwidth remedy payments that Entergy Texas received related to 2006-2008 production costs. In June 2016, Entergy Texas filed an unopposed settlement agreement that added additional over-recovered fuel costs for the months of March and April 2016. The settlement resulted in a $68 million refund. The ALJ approved the refund on an interim basis to be made to most customers over a four-month period beginning with the first billing cycle of July 2016. In July 2016 the PUCT issued an order approving the interim refund. In July 2016, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period April 1, 2013 through March 31, 2016. Under a recent PUCT rule change, a fuel reconciliation is required to be filed at least once every three years and outside of a base rate case filing. During the reconciliation period, Entergy Texas incurred approximately $1.77 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimates an over-recovery balance of approximately $19.3 million , including interest, which Entergy Texas is requesting authority to carry over as the beginning balance for the subsequent reconciliation period beginning Apri1 2016. Entergy Texas also notes, however, that the $19.3 million over collection is currently being refunded to customers as a portion of the interim fuel refund beginning with the first billing cycle of July 2016, discussed above. Entergy Texas also is requesting a prudence finding for each of the fuel-related contracts and arrangements entered into or modified during the reconciliation period that have not been reviewed by the PUCT in a prior proceeding. The PUCT has one year to issue a final order in this proceeding. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC 2015 Rate Case In April 2015, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. The filing notified the APSC of Entergy Arkansas’s intent to implement a formula rate review mechanism pursuant to Arkansas legislation passed in 2015, and requested a retail rate increase of $268.4 million , with a net increase in revenue of $167 million. The filing requested a 10.2% return on common equity. In September 2015 the APSC staff and intervenors filed direct testimony, with the APSC staff recommending a revenue requirement of $217.9 million and a 9.65% return on common equity. In December 2015, Entergy Arkansas, the APSC staff, and certain of the intervenors in the rate case filed with the APSC a joint motion for approval of a settlement of the case that proposed a retail rate increase of approximately $225 million with a net increase in revenue of approximately $133 million ; an authorized return on common equity of 9.75% ; and a formula rate plan tariff that provides a +/- 50 basis point band around the 9.75% allowed return on common equity. A significant portion of the rate increase is related to Entergy Arkansas’s acquisition in March 2016 of Union Power Station Power Block 2 for a base purchase price of $237 million , subject to closing adjustments. The settlement agreement also provided for amortization over a 10-year period of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance. A settlement hearing was held in January 2016. In February 2016 the APSC approved the settlement with one exception that would reduce the retail rate increase proposed in the settlement by $5 million . The settling parties agreed to the APSC modifications in February 2016. The new rates were effective February 24, 2016 and began billing with the first billing cycle of April 2016. In March 2016, Entergy Arkansas made a compliance filing regarding the new rates that included an interim base rate adjustment surcharge, effective with the first billing cycle of April 2016, to recover the incremental revenue requirement for the period February 24, 2016 through March 31, 2016. The interim base rate adjustment surcharge will recover a total of $21.1 million over the nine-month period from April 2016 through December 2016. 2016 Formula Rate Plan Filing In July 2016, Entergy Arkansas filed with the APSC its 2016 formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2017 test period to be below the formula rate plan bandwidth. The filing requested a $67.7 million revenue requirement increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . In October 2016, Entergy Arkansas filed with the APSC revised formula rate plan attachments with an updated request for a $54.4 million revenue requirement increase based on acceptance of certain adjustments and recommendations made by the APSC staff and other intervenors, as well as three additional adjustments identified as appropriate by Entergy Arkansas. Also in October 2016, Entergy Arkansas and all parties filed a joint motion to approve a settlement agreement and waive the hearing scheduled for November 2016. The APSC denied the request to waive the hearing, directed certain witnesses to appear, and stated that approval of the settlement agreement would be addressed by a subsequent order. In November 2016 a hearing was held and the APSC issued an order directing the parties to brief certain issues. The parties to the settlement agreement, who reached agreement on all issues and certain additional provisions related to future filing information, requested an order approving the settlement agreement and the proposed $54.4 million revenue requirement increase and rate adjustment by December 9, 2016. If a final order is not issued by this date, the proposed formula rate plan rate adjustment will become effective December 30, 2016, subject to refund. Advanced Metering Infrastructure (AMI) Filing In September 2016, Entergy Arkansas filed an application seeking an order from the APSC finding that Entergy Arkansas’s deployment of AMI is in the public interest. Entergy Arkansas proposed to replace existing meters with advanced meters that enable two-way data communication; design and build a secure and reliable network to support such communications; and implement support systems. AMI is intended to serve as the foundation of Entergy Arkansas’s modernized power grid. The filing identified a number quantified and unquantified benefits, and Entergy Arkansas provided a cost benefit analysis showing that its AMI deployment is expected to produce a nominal net benefit to customers of $431 million . Entergy Arkansas also sought to continue to include in rate base the remaining book value, approximately $57 million , of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Entergy Arkansas proposed a 15-year depreciable life for the new advanced meters, the three-year deployment of which is expected to begin in 2019. Subject to approval by the APSC, deployment of the communications network is expected to begin in 2018. Entergy Arkansas proposed to include the AMI deployment costs and the quantified benefits in future formula rate plan filings. In order to have certainty around its 2018 projected AMI deployment costs, Entergy Arkansas sought an order from the APSC prior to the hearing on its expected 2017 formula rate plan filing in fourth quarter 2017. Filings with the LPSC Retail Rates - Electric 2015 Formula Rate Plan Filing In May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. The evaluation report reflects an earned return on common equity of 9.07% . As such, no adjustment to base formula rate plan revenue is required. The following other adjustments, however, are required under the formula rate plan: an increase in the legacy Entergy Louisiana additional capacity mechanism of $14.2 million ; a separate increase in legacy Entergy Louisiana revenue of $10 million primarily to reflect the effects of the termination of the System Agreement; an increase in the legacy Entergy Gulf States Louisiana additional capacity mechanism of $0.5 million ; a decrease in legacy Entergy Gulf States Louisiana revenue of $58.7 million primarily to reflect the effects of the termination of the System Agreement; and an increase of $11 million to the MISO cost recovery mechanism. Rates were implemented with the first billing cycle of September 2016, subject to refund. Waterford 3 Replacement Steam Generator Project Following the completion of the Waterford 3 replacement steam generator project, the LPSC undertook a prudence review in connection with a filing made by Entergy Louisiana in April 2013 with regard to the following aspects of the replacement project: 1) project management; 2) cost controls; 3) success in achieving stated objectives; 4) the costs of the replacement project; and 5) the outage length and replacement power costs. In July 2014 the LPSC Staff filed testimony recommending potential project and replacement power cost disallowances of up to $71 million , citing a need for further explanation or documentation from Entergy Louisiana. An intervenor filed testimony recommending disallowance of $141 million of incremental project costs, claiming the steam generator fabricator was imprudent. Entergy Louisiana provided further documentation and explanation requested by the LPSC staff. An evidentiary hearing was held in December 2014. At the hearing the parties maintained the positions reflected in pre-filed testimony. Entergy Louisiana believes that the replacement steam generator costs were prudently incurred and applicable legal principles support their recovery in rates. Nevertheless, Entergy Louisiana recorded a write-off of $16 million of Waterford 3’s plant balance in December 2014 because of the uncertainty at the time associated with the resolution of the prudence review. In December 2015 the ALJ issued a proposed recommendation, which was subsequently finalized, concluding that Entergy Louisiana prudently managed the Waterford 3 replacement steam generator project, including the selection, use, and oversight of contractors, and could not reasonably have anticipated the damage to the steam generators. Nevertheless, the ALJ concluded that Entergy Louisiana was liable for the conduct of its contractor and subcontractor and, therefore, recommended a disallowance of $67 million in capital costs. Additionally, the ALJ concluded that Entergy Louisiana did not sufficiently justify the incurrence of $2 million in replacement power costs during the replacement outage. After considering the progress of the proceeding in light of the ALJ recommendation, Entergy Louisiana recorded in the fourth quarter 2015 approximately $77 million in charges, including a $45 million asset write-off and a $32 million regulatory charge, to reflect that a portion of the assets associated with the Waterford 3 replacement steam generator project is no longer probable of recovery. Entergy Louisiana maintains that the ALJ’s recommendation contains significant factual and legal errors. In October 2016 the parties reached a settlement in this matter. If approved by the LPSC, the settlement effectively would provide for an agreed-upon disallowance of $67 million of plant, which had been previously written off by Entergy Louisiana, as discussed above. The settlement would also require a refund to customers of approximately $43 million , representing the revenues previously collected associated with the disallowed plant, including interest, and $2 million of replacement power costs. Entergy Louisiana had previously recorded provisions for these refunds. Additionally, under the settlement, Entergy Louisiana would provide a one-time credit to customers of approximately $24 million , representing the value of potential future service credits agreed to by the project contractor. The settlement provides that Entergy Louisiana can retain the value associated with these service credits, to the extent they are realized in the future. If the settlement is approved by the LPSC, the refunds and one-time credit to customers would be made in December 2016. Ninemile 6 As discussed in the Form 10-K, in July 2015, Entergy Louisiana submitted to the LPSC a Ninemile 6 compliance filing including an estimate at completion, inclusive of interconnection costs and transmission upgrades, of approximately $648 million , or $76 million less than originally estimated, along with other project details and supporting evidence, to enable the LPSC to review the prudence of Entergy Louisiana’s management of the project. Testimony filed by the LPSC staff generally supports the prudence of the management of the project and recovery of the costs incurred to complete the project. The LPSC staff had questioned the warranty coverage for one element of the project. In March 2016, Entergy Louisiana and the LPSC staff filed a joint motion to suspend the procedural schedule pending the filing of an uncontested joint stipulated settlement. In October 2016 all parties agreed to a stipulation providing that 100% of Ninemile 6 construction costs was prudently incurred and is eligible for recovery from customers, but reserving the LPSC’s rights to review the prudence of Entergy Louisiana’s actions regarding one element of the project. This stipulation is subject to LPSC approval. Union Power Station As discussed in the Form 10-K, in October 2015 the LPSC approved a settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station. In March 2016, Entergy Louisiana acquired Power Blocks 3 and 4 of Union Power Station for an aggregate purchase price of approximately $474 million and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. 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. Parties have requested further proceedings on the prudence of Entergy Louisiana’s decision to deactivate Willow Glen 2 and 4. This matter is pending before an ALJ, and a hearing has been scheduled in March 2017 to determine, under applicable law, whether Willow Glen 2 and 4 units should be returned to service. Retail Rates - Gas In January 2016, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2015. The filing showed an earned return on common equity of 10.22% , which is within the authorized bandwidth, therefore requiring no change in rates. In March 2016 the LPSC staff issued its report stating that the 2015 gas rate stabilization plan filing is in compliance with the exception of several issues that require additional information, explanation, or clarification for which the LPSC staff has reserved the right to further review. In July 2016 the parties to the proceeding filed an unopposed joint report and motion for entry of order accepting report that indicates no outstanding issues remain in the filing. Absent approval of an extension by the LPSC, test year 2015 is the final year under the current gas rate stabilization plan. In February 2016, however, Entergy Louisiana filed a motion requesting to extend the term of the gas rate stabilization plan for an additional three-year term. A procedural schedule has been established, including a hearing in November 2016. The LPSC staff filed testimony supportive of the renewal of the gas rate stabilization plan. The parties submitted a motion indicating that they are working toward development of a settlement that they would seek to have approved at the November 2016 hearing. Filings with the MPSC In March 2016, Entergy Mississippi submitted its formula rate plan 2016 test year filing showing Entergy Mississippi’s projected earned return for the 2016 calendar year to be below the formula rate plan bandwidth. The filing showed a $32.6 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 9.96% , within the formula rate plan bandwidth. In June 2016 the MPSC approved Entergy Mississippi’s joint stipulation with the Mississippi Public Utilities Staff. The joint stipulation provided for a total revenue increase of $23.7 million . The revenue increase includes a $19.4 million increase through the formula rate plan, resulting in a return on common equity point of adjustment of 10.07% . The revenue increase also includes $4.3 million in incremental ad valorem tax expenses to be collected through an updated ad valorem tax adjustment rider. The revenue increase and ad valorem tax adjustment rider were effective with the July 2016 bills. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the terms of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6, the revenue requirement associated with the purchase of Power Block 1 of the Union Power Station, and a credit to customers of $400 thousand monthly beginning June 2016 in recognition of the decrease in other operation and maintenance expenses that would result with the deactivation of Michoud Units 2 and 3. In March 2016, Entergy New Orleans purchased Power Block 1 of the Union Power Station for approximately $237 million and initiated recovery of these costs with March 2016 bills. In July 2016, Entergy New Orleans and the City Council Utility Committee agreed to a temporary increase in the Michoud credit to customers to a total of $1.4 million monthly for August 2016 through December 2016. Internal Restructuring In July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring which would result in the transfer of substantially all of the assets and operations of Entergy New Orleans to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval of the City Council and the FERC. The application provided that if it is approved by the City Council in 2016, Entergy New Orleans would credit retail customers $5 million in each of the years 2016 and 2017. Intervenors filed direct testimony and comments in September 2016 and the City Council advisors filed direct testimony in October 2016. A hearing at the City Council scheduled for October 2016 has been continued until December 2016. In October 2016, Entergy New Orleans filed its rebuttal testimony and therein agreed that, given the extended procedural schedule, the $5 million in proposed 2016 credits would still be paid, although on a different schedule, if the City Council approved the restructuring after 2016 but before the end of the first quarter of 2017. The filing with the FERC has not yet been made, but if the restructuring is approved by the FERC by December 31, 2018, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2018, 2019, and 2020. If City Council and FERC approvals are obtained, Entergy New Orleans expects the restructuring will be consummated by December 31, 2017. It is currently contemplated that Entergy New Orleans would undertake a multi-step restructuring, which would include the following: • Entergy New Orleans would redeem its outstanding preferred stock at a price of approximately $21 million , which includes an expected call premium of approximately $819,000 , plus any accumulated and unpaid dividends. • Entergy New Orleans would convert from a Louisiana corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy New Orleans will allocate substantially all of its assets to a new subsidiary, Entergy New Orleans Power, LLC, a Texas limited liability company (Entergy New Orleans Power), and Entergy New Orleans Power will assume substantially all of the liabilities of Entergy New Orleans, in a transaction regarded as a merger under the TXBOC. Entergy New Orleans will remain in existence and hold the membership interests in Entergy New Orleans Power. • Entergy New Orleans will contribute the membership interests in Entergy New Orleans Power to an affiliate (Entergy Utility Holding Company, LLC
Entergy Arkansas [Member]
Public Utilities Disclosure [Text Block]	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2016, Entergy Arkansas filed its annual rate redetermination pursuant to the production cost allocation rider, which reflected recovery of the production cost allocation rider true-up adjustment of the 2014 and 2015 unrecovered retail balance in the amount of $1.9 million . Additionally, the redetermined rates reflected the recovery of a $1.9 million System Agreement bandwidth remedy payment resulting from a compliance filing pursuant to the FERC’s December 2015 order related to test year 2009 production costs. The rates for the 2016 production cost allocation rider update became effective with the first billing cycle of July 2016, and rates will be effective through June 2017. Entergy Louisiana In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. The LPSC staff issued its audit report in January 2013. The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million , plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates. The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing. Two parties intervened in the proceeding. A procedural schedule was established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC staff report and any issues raised by intervenors. One intervenor sought further proceedings regarding certain issues it raised in its comments on the LPSC staff report. Entergy Louisiana filed responses to both the LPSC staff report and the issues raised by the intervenor. After conducting additional discovery, in April 2016 the LPSC staff consultant issued its supplemental audit report, which concluded that Entergy Louisiana was not imprudent on the issues raised by the intervenor. The intervenor has stated that it does not intend to pursue these issues further. In October 2016 the LPSC staff filed testimony affirming the recommendation in its audit report that nuclear dry fuel storage costs should be realigned to base rates. A procedural schedule has been established for this proceeding, including an evidentiary hearing in November 2016. In December 2011 the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through 2009. In March 2016 the LPSC staff consultant issued its audit report. In its report, the LPSC staff consultant recommended that Entergy Louisiana refund approximately $8.6 million , plus interest, to customers and realign the recovery of approximately $12.7 million from Entergy Gulf States Louisiana’s fuel adjustment clause to base rates. In September 2016 the LPSC staff filed testimony stating that is was no longer recommending a disallowance of $3.4 million of the $8.6 million discussed above, but otherwise maintained positions from its report. Entergy Louisiana has recorded a provision for the estimated outcome of this proceeding. A procedural schedule has been established for this proceeding, including a hearing in December 2016. In June 2016 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. In recognition of the business combination that occurred in 2015, the audit notice was issued to Entergy Louisiana and will also include a review of charges to legacy Entergy Gulf States Louisiana customers prior to the business combination. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment and purchased gas adjustment mechanisms for the period from 2012 through 2015. Discovery has not commenced. Entergy Mississippi Entergy Mississippi had a deferred fuel over-recovery balance of $58.3 million as of May 31, 2015, along with an under-recovery balance of $12.3 million under the power management rider. Pursuant to those tariffs, in July 2015, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider to flow through to customers the approximately $46 million net over-recovery over a six-month period. In August 2015 the MPSC approved the interim adjustments effective with September 2015 bills. In November 2015, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included a projected over-recovery balance of $48 million projected through January 31, 2016. In January 2016 the MPSC approved the redetermined annual factor effective February 1, 2016. The MPSC further ordered, however, that due to the significant change in natural gas price forecasts since Entergy Mississippi’s filing in November 2015, Entergy Mississippi shall file a revised fuel factor with the MPSC no later than February 1, 2016. Pursuant to that order, Entergy Mississippi submitted a revised fuel factor. Additionally, because Entergy Mississippi’s projected over-recovery balance for the period ending January 31, 2017 was $68 million , in February 2016, Entergy Mississippi filed for another interim adjustment to the energy cost factor effective April 2016 to flow through to customers the projected over-recovery balance over a six-month period. That interim adjustment was approved by the MPSC in February 2016 effective for April 2016 bills. Mississippi Attorney General Complaint 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 complaint is wide ranging and relates to tariffs and procedures under which Entergy Mississippi purchases power not generated in Mississippi to meet electricity demand. Entergy believes the complaint is unfounded. In December 2008 the defendant Entergy companies removed the Attorney General’s lawsuit to U.S. District Court in Jackson, Mississippi. The Mississippi attorney general moved to remand the matter to state court. In August 2012 the District Court issued an opinion denying the Attorney General’s motion for remand, finding that the District Court has subject matter jurisdiction under the Class Action Fairness Act. The defendant Entergy companies answered the complaint and filed a counterclaim for relief based upon the Mississippi Public Utilities Act and the Federal Power Act. In May 2009 the defendant Entergy companies filed a motion for judgment on the pleadings asserting grounds of federal preemption, the exclusive jurisdiction of the MPSC, and factual errors in the Attorney General’s complaint. In September 2012 the District Court heard oral argument on Entergy’s motion for judgment on the pleadings. In January 2014 the U.S. Supreme Court issued a decision in which it held that cases brought by attorneys general as the sole plaintiff to enforce state laws were not considered “mass actions” under the Class Action Fairness Act, so as to establish federal subject matter jurisdiction. One day later the Attorney General renewed his motion to remand the Entergy case back to state court, citing the U.S. Supreme Court’s decision. The defendant Entergy companies responded to that motion reiterating the additional grounds asserted for federal question jurisdiction, and the District Court held oral argument on the renewed motion to remand in February 2014. In April 2015 the District Court entered an order denying the renewed motion to remand, holding that the District Court has federal question subject matter jurisdiction. The Attorney General appealed to the U.S. Fifth Circuit Court of Appeals the denial of the motion to remand. In July 2015 the Fifth Circuit issued an order denying the appeal, and the Attorney General subsequently filed a petition for rehearing of the request for interlocutory appeal, which was also denied. In December 2015 the District Court ordered that the parties submit to the court undisputed and disputed facts that are material to the Entergy defendants’ motion for judgment on the pleadings, as well as supplemental briefs regarding the same. Those filings were made in January 2016. In September 2016 the Attorney General filed a mandamus petition with the U.S. Fifth Circuit Court of Appeals in which the Attorney General asked the Fifth Circuit to order the chief judge to reassign this case to another judge. The District Court denied the Entergy companies’ motion for judgment on the pleadings. The Entergy companies filed a motion seeking to amend the District Court’s order denying the Entergy companies’ motion for judgment on the pleadings and allowing an interlocutory appeal. The Fifth Circuit granted the Attorney General’s motion for writ of mandamus and directed the chief judge to assign the case to a new judge. The case has now been reassigned, and the Entergy companies’ motion to amend the order remains pending. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in the open 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 $10.9 million in 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. Both appeals are pending, but the appeals do not stay the PUCT’s decision. The federal appeal is scheduled to be heard in December 2016. In April 2016, Entergy Texas filed with the PUCT an application to refund to customers approximately $56.2 million . The refund resulted from (i) $41.8 million of fuel cost recovery over-collections through February 2016, (ii) the $10.9 million in bandwidth remedy payments, discussed above, that Entergy Texas received related to calendar year 2006 production costs, and (iii) $3.5 million in bandwidth remedy payments that Entergy Texas received related to 2006-2008 production costs. In June 2016, Entergy Texas filed an unopposed settlement agreement that added additional over-recovered fuel costs for the months of March and April 2016. The settlement resulted in a $68 million refund. The ALJ approved the refund on an interim basis to be made to most customers over a four-month period beginning with the first billing cycle of July 2016. In July 2016 the PUCT issued an order approving the interim refund. In July 2016, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period April 1, 2013 through March 31, 2016. Under a recent PUCT rule change, a fuel reconciliation is required to be filed at least once every three years and outside of a base rate case filing. During the reconciliation period, Entergy Texas incurred approximately $1.77 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimates an over-recovery balance of approximately $19.3 million , including interest, which Entergy Texas is requesting authority to carry over as the beginning balance for the subsequent reconciliation period beginning Apri1 2016. Entergy Texas also notes, however, that the $19.3 million over collection is currently being refunded to customers as a portion of the interim fuel refund beginning with the first billing cycle of July 2016, discussed above. Entergy Texas also is requesting a prudence finding for each of the fuel-related contracts and arrangements entered into or modified during the reconciliation period that have not been reviewed by the PUCT in a prior proceeding. The PUCT has one year to issue a final order in this proceeding. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC 2015 Rate Case In April 2015, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. The filing notified the APSC of Entergy Arkansas’s intent to implement a formula rate review mechanism pursuant to Arkansas legislation passed in 2015, and requested a retail rate increase of $268.4 million , with a net increase in revenue of $167 million. The filing requested a 10.2% return on common equity. In September 2015 the APSC staff and intervenors filed direct testimony, with the APSC staff recommending a revenue requirement of $217.9 million and a 9.65% return on common equity. In December 2015, Entergy Arkansas, the APSC staff, and certain of the intervenors in the rate case filed with the APSC a joint motion for approval of a settlement of the case that proposed a retail rate increase of approximately $225 million with a net increase in revenue of approximately $133 million ; an authorized return on common equity of 9.75% ; and a formula rate plan tariff that provides a +/- 50 basis point band around the 9.75% allowed return on common equity. A significant portion of the rate increase is related to Entergy Arkansas’s acquisition in March 2016 of Union Power Station Power Block 2 for a base purchase price of $237 million , subject to closing adjustments. The settlement agreement also provided for amortization over a 10-year period of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance. A settlement hearing was held in January 2016. In February 2016 the APSC approved the settlement with one exception that would reduce the retail rate increase proposed in the settlement by $5 million . The settling parties agreed to the APSC modifications in February 2016. The new rates were effective February 24, 2016 and began billing with the first billing cycle of April 2016. In March 2016, Entergy Arkansas made a compliance filing regarding the new rates that included an interim base rate adjustment surcharge, effective with the first billing cycle of April 2016, to recover the incremental revenue requirement for the period February 24, 2016 through March 31, 2016. The interim base rate adjustment surcharge will recover a total of $21.1 million over the nine-month period from April 2016 through December 2016. 2016 Formula Rate Plan Filing In July 2016, Entergy Arkansas filed with the APSC its 2016 formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2017 test period to be below the formula rate plan bandwidth. The filing requested a $67.7 million revenue requirement increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . In October 2016, Entergy Arkansas filed with the APSC revised formula rate plan attachments with an updated request for a $54.4 million revenue requirement increase based on acceptance of certain adjustments and recommendations made by the APSC staff and other intervenors, as well as three additional adjustments identified as appropriate by Entergy Arkansas. Also in October 2016, Entergy Arkansas and all parties filed a joint motion to approve a settlement agreement and waive the hearing scheduled for November 2016. The APSC denied the request to waive the hearing, directed certain witnesses to appear, and stated that approval of the settlement agreement would be addressed by a subsequent order. In November 2016 a hearing was held and the APSC issued an order directing the parties to brief certain issues. The parties to the settlement agreement, who reached agreement on all issues and certain additional provisions related to future filing information, requested an order approving the settlement agreement and the proposed $54.4 million revenue requirement increase and rate adjustment by December 9, 2016. If a final order is not issued by this date, the proposed formula rate plan rate adjustment will become effective December 30, 2016, subject to refund. Advanced Metering Infrastructure (AMI) Filing In September 2016, Entergy Arkansas filed an application seeking an order from the APSC finding that Entergy Arkansas’s deployment of AMI is in the public interest. Entergy Arkansas proposed to replace existing meters with advanced meters that enable two-way data communication; design and build a secure and reliable network to support such communications; and implement support systems. AMI is intended to serve as the foundation of Entergy Arkansas’s modernized power grid. The filing identified a number quantified and unquantified benefits, and Entergy Arkansas provided a cost benefit analysis showing that its AMI deployment is expected to produce a nominal net benefit to customers of $431 million . Entergy Arkansas also sought to continue to include in rate base the remaining book value, approximately $57 million , of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Entergy Arkansas proposed a 15-year depreciable life for the new advanced meters, the three-year deployment of which is expected to begin in 2019. Subject to approval by the APSC, deployment of the communications network is expected to begin in 2018. Entergy Arkansas proposed to include the AMI deployment costs and the quantified benefits in future formula rate plan filings. In order to have certainty around its 2018 projected AMI deployment costs, Entergy Arkansas sought an order from the APSC prior to the hearing on its expected 2017 formula rate plan filing in fourth quarter 2017. Filings with the LPSC Retail Rates - Electric 2015 Formula Rate Plan Filing In May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. The evaluation report reflects an earned return on common equity of 9.07% . As such, no adjustment to base formula rate plan revenue is required. The following other adjustments, however, are required under the formula rate plan: an increase in the legacy Entergy Louisiana additional capacity mechanism of $14.2 million ; a separate increase in legacy Entergy Louisiana revenue of $10 million primarily to reflect the effects of the termination of the System Agreement; an increase in the legacy Entergy Gulf States Louisiana additional capacity mechanism of $0.5 million ; a decrease in legacy Entergy Gulf States Louisiana revenue of $58.7 million primarily to reflect the effects of the termination of the System Agreement; and an increase of $11 million to the MISO cost recovery mechanism. Rates were implemented with the first billing cycle of September 2016, subject to refund. Waterford 3 Replacement Steam Generator Project Following the completion of the Waterford 3 replacement steam generator project, the LPSC undertook a prudence review in connection with a filing made by Entergy Louisiana in April 2013 with regard to the following aspects of the replacement project: 1) project management; 2) cost controls; 3) success in achieving stated objectives; 4) the costs of the replacement project; and 5) the outage length and replacement power costs. In July 2014 the LPSC Staff filed testimony recommending potential project and replacement power cost disallowances of up to $71 million , citing a need for further explanation or documentation from Entergy Louisiana. An intervenor filed testimony recommending disallowance of $141 million of incremental project costs, claiming the steam generator fabricator was imprudent. Entergy Louisiana provided further documentation and explanation requested by the LPSC staff. An evidentiary hearing was held in December 2014. At the hearing the parties maintained the positions reflected in pre-filed testimony. Entergy Louisiana believes that the replacement steam generator costs were prudently incurred and applicable legal principles support their recovery in rates. Nevertheless, Entergy Louisiana recorded a write-off of $16 million of Waterford 3’s plant balance in December 2014 because of the uncertainty at the time associated with the resolution of the prudence review. In December 2015 the ALJ issued a proposed recommendation, which was subsequently finalized, concluding that Entergy Louisiana prudently managed the Waterford 3 replacement steam generator project, including the selection, use, and oversight of contractors, and could not reasonably have anticipated the damage to the steam generators. Nevertheless, the ALJ concluded that Entergy Louisiana was liable for the conduct of its contractor and subcontractor and, therefore, recommended a disallowance of $67 million in capital costs. Additionally, the ALJ concluded that Entergy Louisiana did not sufficiently justify the incurrence of $2 million in replacement power costs during the replacement outage. After considering the progress of the proceeding in light of the ALJ recommendation, Entergy Louisiana recorded in the fourth quarter 2015 approximately $77 million in charges, including a $45 million asset write-off and a $32 million regulatory charge, to reflect that a portion of the assets associated with the Waterford 3 replacement steam generator project is no longer probable of recovery. Entergy Louisiana maintains that the ALJ’s recommendation contains significant factual and legal errors. In October 2016 the parties reached a settlement in this matter. If approved by the LPSC, the settlement effectively would provide for an agreed-upon disallowance of $67 million of plant, which had been previously written off by Entergy Louisiana, as discussed above. The settlement would also require a refund to customers of approximately $43 million , representing the revenues previously collected associated with the disallowed plant, including interest, and $2 million of replacement power costs. Entergy Louisiana had previously recorded provisions for these refunds. Additionally, under the settlement, Entergy Louisiana would provide a one-time credit to customers of approximately $24 million , representing the value of potential future service credits agreed to by the project contractor. The settlement provides that Entergy Louisiana can retain the value associated with these service credits, to the extent they are realized in the future. If the settlement is approved by the LPSC, the refunds and one-time credit to customers would be made in December 2016. Ninemile 6 As discussed in the Form 10-K, in July 2015, Entergy Louisiana submitted to the LPSC a Ninemile 6 compliance filing including an estimate at completion, inclusive of interconnection costs and transmission upgrades, of approximately $648 million , or $76 million less than originally estimated, along with other project details and supporting evidence, to enable the LPSC to review the prudence of Entergy Louisiana’s management of the project. Testimony filed by the LPSC staff generally supports the prudence of the management of the project and recovery of the costs incurred to complete the project. The LPSC staff had questioned the warranty coverage for one element of the project. In March 2016, Entergy Louisiana and the LPSC staff filed a joint motion to suspend the procedural schedule pending the filing of an uncontested joint stipulated settlement. In October 2016 all parties agreed to a stipulation providing that 100% of Ninemile 6 construction costs was prudently incurred and is eligible for recovery from customers, but reserving the LPSC’s rights to review the prudence of Entergy Louisiana’s actions regarding one element of the project. This stipulation is subject to LPSC approval. Union Power Station As discussed in the Form 10-K, in October 2015 the LPSC approved a settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station. In March 2016, Entergy Louisiana acquired Power Blocks 3 and 4 of Union Power Station for an aggregate purchase price of approximately $474 million and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. 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. Parties have requested further proceedings on the prudence of Entergy Louisiana’s decision to deactivate Willow Glen 2 and 4. This matter is pending before an ALJ, and a hearing has been scheduled in March 2017 to determine, under applicable law, whether Willow Glen 2 and 4 units should be returned to service. Retail Rates - Gas In January 2016, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2015. The filing showed an earned return on common equity of 10.22% , which is within the authorized bandwidth, therefore requiring no change in rates. In March 2016 the LPSC staff issued its report stating that the 2015 gas rate stabilization plan filing is in compliance with the exception of several issues that require additional information, explanation, or clarification for which the LPSC staff has reserved the right to further review. In July 2016 the parties to the proceeding filed an unopposed joint report and motion for entry of order accepting report that indicates no outstanding issues remain in the filing. Absent approval of an extension by the LPSC, test year 2015 is the final year under the current gas rate stabilization plan. In February 2016, however, Entergy Louisiana filed a motion requesting to extend the term of the gas rate stabilization plan for an additional three-year term. A procedural schedule has been established, including a hearing in November 2016. The LPSC staff filed testimony supportive of the renewal of the gas rate stabilization plan. The parties submitted a motion indicating that they are working toward development of a settlement that they would seek to have approved at the November 2016 hearing. Filings with the MPSC In March 2016, Entergy Mississippi submitted its formula rate plan 2016 test year filing showing Entergy Mississippi’s projected earned return for the 2016 calendar year to be below the formula rate plan bandwidth. The filing showed a $32.6 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 9.96% , within the formula rate plan bandwidth. In June 2016 the MPSC approved Entergy Mississippi’s joint stipulation with the Mississippi Public Utilities Staff. The joint stipulation provided for a total revenue increase of $23.7 million . The revenue increase includes a $19.4 million increase through the formula rate plan, resulting in a return on common equity point of adjustment of 10.07% . The revenue increase also includes $4.3 million in incremental ad valorem tax expenses to be collected through an updated ad valorem tax adjustment rider. The revenue increase and ad valorem tax adjustment rider were effective with the July 2016 bills. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the terms of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6, the revenue requirement associated with the purchase of Power Block 1 of the Union Power Station, and a credit to customers of $400 thousand monthly beginning June 2016 in recognition of the decrease in other operation and maintenance expenses that would result with the deactivation of Michoud Units 2 and 3. In March 2016, Entergy New Orleans purchased Power Block 1 of the Union Power Station for approximately $237 million and initiated recovery of these costs with March 2016 bills. In July 2016, Entergy New Orleans and the City Council Utility Committee agreed to a temporary increase in the Michoud credit to customers to a total of $1.4 million monthly for August 2016 through December 2016. Internal Restructuring In July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring which would result in the transfer of substantially all of the assets and operations of Entergy New Orleans to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval of the City Council and the FERC. The application provided that if it is approved by the City Council in 2016, Entergy New Orleans would credit retail customers $5 million in each of the years 2016 and 2017. Intervenors filed direct testimony and comments in September 2016 and the City Council advisors filed direct testimony in October 2016. A hearing at the City Council scheduled for October 2016 has been continued until December 2016. In October 2016, Entergy New Orleans filed its rebuttal testimony and therein agreed that, given the extended procedural schedule, the $5 million in proposed 2016 credits would still be paid, although on a different schedule, if the City Council approved the restructuring after 2016 but before the end of the first quarter of 2017. The filing with the FERC has not yet been made, but if the restructuring is approved by the FERC by December 31, 2018, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2018, 2019, and 2020. If City Council and FERC approvals are obtained, Entergy New Orleans expects the restructuring will be consummated by December 31, 2017. It is currently contemplated that Entergy New Orleans would undertake a multi-step restructuring, which would include the following: • Entergy New Orleans would redeem its outstanding preferred stock at a price of approximately $21 million , which includes an expected call premium of approximately $819,000 , plus any accumulated and unpaid dividends. • Entergy New Orleans would convert from a Louisiana corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy New Orleans will allocate substantially all of its assets to a new subsidiary, Entergy New Orleans Power, LLC, a Texas limited liability company (Entergy New Orleans Power), and Entergy New Orleans Power will assume substantially all of the liabilities of Entergy New Orleans, in a transaction regarded as a merger under the TXBOC. Entergy New Orleans will remain in existence and hold the membership interests in Entergy New Orleans Power. • Entergy New Orleans will contribute the membership interests in Entergy New Orleans Power to an affiliate (Entergy Utility Holding Company, LLC
Entergy Louisiana [Member]
Public Utilities Disclosure [Text Block]	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2016, Entergy Arkansas filed its annual rate redetermination pursuant to the production cost allocation rider, which reflected recovery of the production cost allocation rider true-up adjustment of the 2014 and 2015 unrecovered retail balance in the amount of $1.9 million . Additionally, the redetermined rates reflected the recovery of a $1.9 million System Agreement bandwidth remedy payment resulting from a compliance filing pursuant to the FERC’s December 2015 order related to test year 2009 production costs. The rates for the 2016 production cost allocation rider update became effective with the first billing cycle of July 2016, and rates will be effective through June 2017. Entergy Louisiana In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. The LPSC staff issued its audit report in January 2013. The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million , plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates. The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing. Two parties intervened in the proceeding. A procedural schedule was established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC staff report and any issues raised by intervenors. One intervenor sought further proceedings regarding certain issues it raised in its comments on the LPSC staff report. Entergy Louisiana filed responses to both the LPSC staff report and the issues raised by the intervenor. After conducting additional discovery, in April 2016 the LPSC staff consultant issued its supplemental audit report, which concluded that Entergy Louisiana was not imprudent on the issues raised by the intervenor. The intervenor has stated that it does not intend to pursue these issues further. In October 2016 the LPSC staff filed testimony affirming the recommendation in its audit report that nuclear dry fuel storage costs should be realigned to base rates. A procedural schedule has been established for this proceeding, including an evidentiary hearing in November 2016. In December 2011 the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through 2009. In March 2016 the LPSC staff consultant issued its audit report. In its report, the LPSC staff consultant recommended that Entergy Louisiana refund approximately $8.6 million , plus interest, to customers and realign the recovery of approximately $12.7 million from Entergy Gulf States Louisiana’s fuel adjustment clause to base rates. In September 2016 the LPSC staff filed testimony stating that is was no longer recommending a disallowance of $3.4 million of the $8.6 million discussed above, but otherwise maintained positions from its report. Entergy Louisiana has recorded a provision for the estimated outcome of this proceeding. A procedural schedule has been established for this proceeding, including a hearing in December 2016. In June 2016 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. In recognition of the business combination that occurred in 2015, the audit notice was issued to Entergy Louisiana and will also include a review of charges to legacy Entergy Gulf States Louisiana customers prior to the business combination. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment and purchased gas adjustment mechanisms for the period from 2012 through 2015. Discovery has not commenced. Entergy Mississippi Entergy Mississippi had a deferred fuel over-recovery balance of $58.3 million as of May 31, 2015, along with an under-recovery balance of $12.3 million under the power management rider. Pursuant to those tariffs, in July 2015, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider to flow through to customers the approximately $46 million net over-recovery over a six-month period. In August 2015 the MPSC approved the interim adjustments effective with September 2015 bills. In November 2015, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included a projected over-recovery balance of $48 million projected through January 31, 2016. In January 2016 the MPSC approved the redetermined annual factor effective February 1, 2016. The MPSC further ordered, however, that due to the significant change in natural gas price forecasts since Entergy Mississippi’s filing in November 2015, Entergy Mississippi shall file a revised fuel factor with the MPSC no later than February 1, 2016. Pursuant to that order, Entergy Mississippi submitted a revised fuel factor. Additionally, because Entergy Mississippi’s projected over-recovery balance for the period ending January 31, 2017 was $68 million , in February 2016, Entergy Mississippi filed for another interim adjustment to the energy cost factor effective April 2016 to flow through to customers the projected over-recovery balance over a six-month period. That interim adjustment was approved by the MPSC in February 2016 effective for April 2016 bills. Mississippi Attorney General Complaint 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 complaint is wide ranging and relates to tariffs and procedures under which Entergy Mississippi purchases power not generated in Mississippi to meet electricity demand. Entergy believes the complaint is unfounded. In December 2008 the defendant Entergy companies removed the Attorney General’s lawsuit to U.S. District Court in Jackson, Mississippi. The Mississippi attorney general moved to remand the matter to state court. In August 2012 the District Court issued an opinion denying the Attorney General’s motion for remand, finding that the District Court has subject matter jurisdiction under the Class Action Fairness Act. The defendant Entergy companies answered the complaint and filed a counterclaim for relief based upon the Mississippi Public Utilities Act and the Federal Power Act. In May 2009 the defendant Entergy companies filed a motion for judgment on the pleadings asserting grounds of federal preemption, the exclusive jurisdiction of the MPSC, and factual errors in the Attorney General’s complaint. In September 2012 the District Court heard oral argument on Entergy’s motion for judgment on the pleadings. In January 2014 the U.S. Supreme Court issued a decision in which it held that cases brought by attorneys general as the sole plaintiff to enforce state laws were not considered “mass actions” under the Class Action Fairness Act, so as to establish federal subject matter jurisdiction. One day later the Attorney General renewed his motion to remand the Entergy case back to state court, citing the U.S. Supreme Court’s decision. The defendant Entergy companies responded to that motion reiterating the additional grounds asserted for federal question jurisdiction, and the District Court held oral argument on the renewed motion to remand in February 2014. In April 2015 the District Court entered an order denying the renewed motion to remand, holding that the District Court has federal question subject matter jurisdiction. The Attorney General appealed to the U.S. Fifth Circuit Court of Appeals the denial of the motion to remand. In July 2015 the Fifth Circuit issued an order denying the appeal, and the Attorney General subsequently filed a petition for rehearing of the request for interlocutory appeal, which was also denied. In December 2015 the District Court ordered that the parties submit to the court undisputed and disputed facts that are material to the Entergy defendants’ motion for judgment on the pleadings, as well as supplemental briefs regarding the same. Those filings were made in January 2016. In September 2016 the Attorney General filed a mandamus petition with the U.S. Fifth Circuit Court of Appeals in which the Attorney General asked the Fifth Circuit to order the chief judge to reassign this case to another judge. The District Court denied the Entergy companies’ motion for judgment on the pleadings. The Entergy companies filed a motion seeking to amend the District Court’s order denying the Entergy companies’ motion for judgment on the pleadings and allowing an interlocutory appeal. The Fifth Circuit granted the Attorney General’s motion for writ of mandamus and directed the chief judge to assign the case to a new judge. The case has now been reassigned, and the Entergy companies’ motion to amend the order remains pending. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in the open 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 $10.9 million in 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. Both appeals are pending, but the appeals do not stay the PUCT’s decision. The federal appeal is scheduled to be heard in December 2016. In April 2016, Entergy Texas filed with the PUCT an application to refund to customers approximately $56.2 million . The refund resulted from (i) $41.8 million of fuel cost recovery over-collections through February 2016, (ii) the $10.9 million in bandwidth remedy payments, discussed above, that Entergy Texas received related to calendar year 2006 production costs, and (iii) $3.5 million in bandwidth remedy payments that Entergy Texas received related to 2006-2008 production costs. In June 2016, Entergy Texas filed an unopposed settlement agreement that added additional over-recovered fuel costs for the months of March and April 2016. The settlement resulted in a $68 million refund. The ALJ approved the refund on an interim basis to be made to most customers over a four-month period beginning with the first billing cycle of July 2016. In July 2016 the PUCT issued an order approving the interim refund. In July 2016, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period April 1, 2013 through March 31, 2016. Under a recent PUCT rule change, a fuel reconciliation is required to be filed at least once every three years and outside of a base rate case filing. During the reconciliation period, Entergy Texas incurred approximately $1.77 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimates an over-recovery balance of approximately $19.3 million , including interest, which Entergy Texas is requesting authority to carry over as the beginning balance for the subsequent reconciliation period beginning Apri1 2016. Entergy Texas also notes, however, that the $19.3 million over collection is currently being refunded to customers as a portion of the interim fuel refund beginning with the first billing cycle of July 2016, discussed above. Entergy Texas also is requesting a prudence finding for each of the fuel-related contracts and arrangements entered into or modified during the reconciliation period that have not been reviewed by the PUCT in a prior proceeding. The PUCT has one year to issue a final order in this proceeding. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC 2015 Rate Case In April 2015, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. The filing notified the APSC of Entergy Arkansas’s intent to implement a formula rate review mechanism pursuant to Arkansas legislation passed in 2015, and requested a retail rate increase of $268.4 million , with a net increase in revenue of $167 million. The filing requested a 10.2% return on common equity. In September 2015 the APSC staff and intervenors filed direct testimony, with the APSC staff recommending a revenue requirement of $217.9 million and a 9.65% return on common equity. In December 2015, Entergy Arkansas, the APSC staff, and certain of the intervenors in the rate case filed with the APSC a joint motion for approval of a settlement of the case that proposed a retail rate increase of approximately $225 million with a net increase in revenue of approximately $133 million ; an authorized return on common equity of 9.75% ; and a formula rate plan tariff that provides a +/- 50 basis point band around the 9.75% allowed return on common equity. A significant portion of the rate increase is related to Entergy Arkansas’s acquisition in March 2016 of Union Power Station Power Block 2 for a base purchase price of $237 million , subject to closing adjustments. The settlement agreement also provided for amortization over a 10-year period of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance. A settlement hearing was held in January 2016. In February 2016 the APSC approved the settlement with one exception that would reduce the retail rate increase proposed in the settlement by $5 million . The settling parties agreed to the APSC modifications in February 2016. The new rates were effective February 24, 2016 and began billing with the first billing cycle of April 2016. In March 2016, Entergy Arkansas made a compliance filing regarding the new rates that included an interim base rate adjustment surcharge, effective with the first billing cycle of April 2016, to recover the incremental revenue requirement for the period February 24, 2016 through March 31, 2016. The interim base rate adjustment surcharge will recover a total of $21.1 million over the nine-month period from April 2016 through December 2016. 2016 Formula Rate Plan Filing In July 2016, Entergy Arkansas filed with the APSC its 2016 formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2017 test period to be below the formula rate plan bandwidth. The filing requested a $67.7 million revenue requirement increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . In October 2016, Entergy Arkansas filed with the APSC revised formula rate plan attachments with an updated request for a $54.4 million revenue requirement increase based on acceptance of certain adjustments and recommendations made by the APSC staff and other intervenors, as well as three additional adjustments identified as appropriate by Entergy Arkansas. Also in October 2016, Entergy Arkansas and all parties filed a joint motion to approve a settlement agreement and waive the hearing scheduled for November 2016. The APSC denied the request to waive the hearing, directed certain witnesses to appear, and stated that approval of the settlement agreement would be addressed by a subsequent order. In November 2016 a hearing was held and the APSC issued an order directing the parties to brief certain issues. The parties to the settlement agreement, who reached agreement on all issues and certain additional provisions related to future filing information, requested an order approving the settlement agreement and the proposed $54.4 million revenue requirement increase and rate adjustment by December 9, 2016. If a final order is not issued by this date, the proposed formula rate plan rate adjustment will become effective December 30, 2016, subject to refund. Advanced Metering Infrastructure (AMI) Filing In September 2016, Entergy Arkansas filed an application seeking an order from the APSC finding that Entergy Arkansas’s deployment of AMI is in the public interest. Entergy Arkansas proposed to replace existing meters with advanced meters that enable two-way data communication; design and build a secure and reliable network to support such communications; and implement support systems. AMI is intended to serve as the foundation of Entergy Arkansas’s modernized power grid. The filing identified a number quantified and unquantified benefits, and Entergy Arkansas provided a cost benefit analysis showing that its AMI deployment is expected to produce a nominal net benefit to customers of $431 million . Entergy Arkansas also sought to continue to include in rate base the remaining book value, approximately $57 million , of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Entergy Arkansas proposed a 15-year depreciable life for the new advanced meters, the three-year deployment of which is expected to begin in 2019. Subject to approval by the APSC, deployment of the communications network is expected to begin in 2018. Entergy Arkansas proposed to include the AMI deployment costs and the quantified benefits in future formula rate plan filings. In order to have certainty around its 2018 projected AMI deployment costs, Entergy Arkansas sought an order from the APSC prior to the hearing on its expected 2017 formula rate plan filing in fourth quarter 2017. Filings with the LPSC Retail Rates - Electric 2015 Formula Rate Plan Filing In May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. The evaluation report reflects an earned return on common equity of 9.07% . As such, no adjustment to base formula rate plan revenue is required. The following other adjustments, however, are required under the formula rate plan: an increase in the legacy Entergy Louisiana additional capacity mechanism of $14.2 million ; a separate increase in legacy Entergy Louisiana revenue of $10 million primarily to reflect the effects of the termination of the System Agreement; an increase in the legacy Entergy Gulf States Louisiana additional capacity mechanism of $0.5 million ; a decrease in legacy Entergy Gulf States Louisiana revenue of $58.7 million primarily to reflect the effects of the termination of the System Agreement; and an increase of $11 million to the MISO cost recovery mechanism. Rates were implemented with the first billing cycle of September 2016, subject to refund. Waterford 3 Replacement Steam Generator Project Following the completion of the Waterford 3 replacement steam generator project, the LPSC undertook a prudence review in connection with a filing made by Entergy Louisiana in April 2013 with regard to the following aspects of the replacement project: 1) project management; 2) cost controls; 3) success in achieving stated objectives; 4) the costs of the replacement project; and 5) the outage length and replacement power costs. In July 2014 the LPSC Staff filed testimony recommending potential project and replacement power cost disallowances of up to $71 million , citing a need for further explanation or documentation from Entergy Louisiana. An intervenor filed testimony recommending disallowance of $141 million of incremental project costs, claiming the steam generator fabricator was imprudent. Entergy Louisiana provided further documentation and explanation requested by the LPSC staff. An evidentiary hearing was held in December 2014. At the hearing the parties maintained the positions reflected in pre-filed testimony. Entergy Louisiana believes that the replacement steam generator costs were prudently incurred and applicable legal principles support their recovery in rates. Nevertheless, Entergy Louisiana recorded a write-off of $16 million of Waterford 3’s plant balance in December 2014 because of the uncertainty at the time associated with the resolution of the prudence review. In December 2015 the ALJ issued a proposed recommendation, which was subsequently finalized, concluding that Entergy Louisiana prudently managed the Waterford 3 replacement steam generator project, including the selection, use, and oversight of contractors, and could not reasonably have anticipated the damage to the steam generators. Nevertheless, the ALJ concluded that Entergy Louisiana was liable for the conduct of its contractor and subcontractor and, therefore, recommended a disallowance of $67 million in capital costs. Additionally, the ALJ concluded that Entergy Louisiana did not sufficiently justify the incurrence of $2 million in replacement power costs during the replacement outage. After considering the progress of the proceeding in light of the ALJ recommendation, Entergy Louisiana recorded in the fourth quarter 2015 approximately $77 million in charges, including a $45 million asset write-off and a $32 million regulatory charge, to reflect that a portion of the assets associated with the Waterford 3 replacement steam generator project is no longer probable of recovery. Entergy Louisiana maintains that the ALJ’s recommendation contains significant factual and legal errors. In October 2016 the parties reached a settlement in this matter. If approved by the LPSC, the settlement effectively would provide for an agreed-upon disallowance of $67 million of plant, which had been previously written off by Entergy Louisiana, as discussed above. The settlement would also require a refund to customers of approximately $43 million , representing the revenues previously collected associated with the disallowed plant, including interest, and $2 million of replacement power costs. Entergy Louisiana had previously recorded provisions for these refunds. Additionally, under the settlement, Entergy Louisiana would provide a one-time credit to customers of approximately $24 million , representing the value of potential future service credits agreed to by the project contractor. The settlement provides that Entergy Louisiana can retain the value associated with these service credits, to the extent they are realized in the future. If the settlement is approved by the LPSC, the refunds and one-time credit to customers would be made in December 2016. Ninemile 6 As discussed in the Form 10-K, in July 2015, Entergy Louisiana submitted to the LPSC a Ninemile 6 compliance filing including an estimate at completion, inclusive of interconnection costs and transmission upgrades, of approximately $648 million , or $76 million less than originally estimated, along with other project details and supporting evidence, to enable the LPSC to review the prudence of Entergy Louisiana’s management of the project. Testimony filed by the LPSC staff generally supports the prudence of the management of the project and recovery of the costs incurred to complete the project. The LPSC staff had questioned the warranty coverage for one element of the project. In March 2016, Entergy Louisiana and the LPSC staff filed a joint motion to suspend the procedural schedule pending the filing of an uncontested joint stipulated settlement. In October 2016 all parties agreed to a stipulation providing that 100% of Ninemile 6 construction costs was prudently incurred and is eligible for recovery from customers, but reserving the LPSC’s rights to review the prudence of Entergy Louisiana’s actions regarding one element of the project. This stipulation is subject to LPSC approval. Union Power Station As discussed in the Form 10-K, in October 2015 the LPSC approved a settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station. In March 2016, Entergy Louisiana acquired Power Blocks 3 and 4 of Union Power Station for an aggregate purchase price of approximately $474 million and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. 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. Parties have requested further proceedings on the prudence of Entergy Louisiana’s decision to deactivate Willow Glen 2 and 4. This matter is pending before an ALJ, and a hearing has been scheduled in March 2017 to determine, under applicable law, whether Willow Glen 2 and 4 units should be returned to service. Retail Rates - Gas In January 2016, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2015. The filing showed an earned return on common equity of 10.22% , which is within the authorized bandwidth, therefore requiring no change in rates. In March 2016 the LPSC staff issued its report stating that the 2015 gas rate stabilization plan filing is in compliance with the exception of several issues that require additional information, explanation, or clarification for which the LPSC staff has reserved the right to further review. In July 2016 the parties to the proceeding filed an unopposed joint report and motion for entry of order accepting report that indicates no outstanding issues remain in the filing. Absent approval of an extension by the LPSC, test year 2015 is the final year under the current gas rate stabilization plan. In February 2016, however, Entergy Louisiana filed a motion requesting to extend the term of the gas rate stabilization plan for an additional three-year term. A procedural schedule has been established, including a hearing in November 2016. The LPSC staff filed testimony supportive of the renewal of the gas rate stabilization plan. The parties submitted a motion indicating that they are working toward development of a settlement that they would seek to have approved at the November 2016 hearing. Filings with the MPSC In March 2016, Entergy Mississippi submitted its formula rate plan 2016 test year filing showing Entergy Mississippi’s projected earned return for the 2016 calendar year to be below the formula rate plan bandwidth. The filing showed a $32.6 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 9.96% , within the formula rate plan bandwidth. In June 2016 the MPSC approved Entergy Mississippi’s joint stipulation with the Mississippi Public Utilities Staff. The joint stipulation provided for a total revenue increase of $23.7 million . The revenue increase includes a $19.4 million increase through the formula rate plan, resulting in a return on common equity point of adjustment of 10.07% . The revenue increase also includes $4.3 million in incremental ad valorem tax expenses to be collected through an updated ad valorem tax adjustment rider. The revenue increase and ad valorem tax adjustment rider were effective with the July 2016 bills. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the terms of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6, the revenue requirement associated with the purchase of Power Block 1 of the Union Power Station, and a credit to customers of $400 thousand monthly beginning June 2016 in recognition of the decrease in other operation and maintenance expenses that would result with the deactivation of Michoud Units 2 and 3. In March 2016, Entergy New Orleans purchased Power Block 1 of the Union Power Station for approximately $237 million and initiated recovery of these costs with March 2016 bills. In July 2016, Entergy New Orleans and the City Council Utility Committee agreed to a temporary increase in the Michoud credit to customers to a total of $1.4 million monthly for August 2016 through December 2016. Internal Restructuring In July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring which would result in the transfer of substantially all of the assets and operations of Entergy New Orleans to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval of the City Council and the FERC. The application provided that if it is approved by the City Council in 2016, Entergy New Orleans would credit retail customers $5 million in each of the years 2016 and 2017. Intervenors filed direct testimony and comments in September 2016 and the City Council advisors filed direct testimony in October 2016. A hearing at the City Council scheduled for October 2016 has been continued until December 2016. In October 2016, Entergy New Orleans filed its rebuttal testimony and therein agreed that, given the extended procedural schedule, the $5 million in proposed 2016 credits would still be paid, although on a different schedule, if the City Council approved the restructuring after 2016 but before the end of the first quarter of 2017. The filing with the FERC has not yet been made, but if the restructuring is approved by the FERC by December 31, 2018, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2018, 2019, and 2020. If City Council and FERC approvals are obtained, Entergy New Orleans expects the restructuring will be consummated by December 31, 2017. It is currently contemplated that Entergy New Orleans would undertake a multi-step restructuring, which would include the following: • Entergy New Orleans would redeem its outstanding preferred stock at a price of approximately $21 million , which includes an expected call premium of approximately $819,000 , plus any accumulated and unpaid dividends. • Entergy New Orleans would convert from a Louisiana corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy New Orleans will allocate substantially all of its assets to a new subsidiary, Entergy New Orleans Power, LLC, a Texas limited liability company (Entergy New Orleans Power), and Entergy New Orleans Power will assume substantially all of the liabilities of Entergy New Orleans, in a transaction regarded as a merger under the TXBOC. Entergy New Orleans will remain in existence and hold the membership interests in Entergy New Orleans Power. • Entergy New Orleans will contribute the membership interests in Entergy New Orleans Power to an affiliate (Entergy Utility Holding Company, LLC
Entergy Mississippi [Member]
Public Utilities Disclosure [Text Block]	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2016, Entergy Arkansas filed its annual rate redetermination pursuant to the production cost allocation rider, which reflected recovery of the production cost allocation rider true-up adjustment of the 2014 and 2015 unrecovered retail balance in the amount of $1.9 million . Additionally, the redetermined rates reflected the recovery of a $1.9 million System Agreement bandwidth remedy payment resulting from a compliance filing pursuant to the FERC’s December 2015 order related to test year 2009 production costs. The rates for the 2016 production cost allocation rider update became effective with the first billing cycle of July 2016, and rates will be effective through June 2017. Entergy Louisiana In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. The LPSC staff issued its audit report in January 2013. The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million , plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates. The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing. Two parties intervened in the proceeding. A procedural schedule was established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC staff report and any issues raised by intervenors. One intervenor sought further proceedings regarding certain issues it raised in its comments on the LPSC staff report. Entergy Louisiana filed responses to both the LPSC staff report and the issues raised by the intervenor. After conducting additional discovery, in April 2016 the LPSC staff consultant issued its supplemental audit report, which concluded that Entergy Louisiana was not imprudent on the issues raised by the intervenor. The intervenor has stated that it does not intend to pursue these issues further. In October 2016 the LPSC staff filed testimony affirming the recommendation in its audit report that nuclear dry fuel storage costs should be realigned to base rates. A procedural schedule has been established for this proceeding, including an evidentiary hearing in November 2016. In December 2011 the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through 2009. In March 2016 the LPSC staff consultant issued its audit report. In its report, the LPSC staff consultant recommended that Entergy Louisiana refund approximately $8.6 million , plus interest, to customers and realign the recovery of approximately $12.7 million from Entergy Gulf States Louisiana’s fuel adjustment clause to base rates. In September 2016 the LPSC staff filed testimony stating that is was no longer recommending a disallowance of $3.4 million of the $8.6 million discussed above, but otherwise maintained positions from its report. Entergy Louisiana has recorded a provision for the estimated outcome of this proceeding. A procedural schedule has been established for this proceeding, including a hearing in December 2016. In June 2016 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. In recognition of the business combination that occurred in 2015, the audit notice was issued to Entergy Louisiana and will also include a review of charges to legacy Entergy Gulf States Louisiana customers prior to the business combination. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment and purchased gas adjustment mechanisms for the period from 2012 through 2015. Discovery has not commenced. Entergy Mississippi Entergy Mississippi had a deferred fuel over-recovery balance of $58.3 million as of May 31, 2015, along with an under-recovery balance of $12.3 million under the power management rider. Pursuant to those tariffs, in July 2015, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider to flow through to customers the approximately $46 million net over-recovery over a six-month period. In August 2015 the MPSC approved the interim adjustments effective with September 2015 bills. In November 2015, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included a projected over-recovery balance of $48 million projected through January 31, 2016. In January 2016 the MPSC approved the redetermined annual factor effective February 1, 2016. The MPSC further ordered, however, that due to the significant change in natural gas price forecasts since Entergy Mississippi’s filing in November 2015, Entergy Mississippi shall file a revised fuel factor with the MPSC no later than February 1, 2016. Pursuant to that order, Entergy Mississippi submitted a revised fuel factor. Additionally, because Entergy Mississippi’s projected over-recovery balance for the period ending January 31, 2017 was $68 million , in February 2016, Entergy Mississippi filed for another interim adjustment to the energy cost factor effective April 2016 to flow through to customers the projected over-recovery balance over a six-month period. That interim adjustment was approved by the MPSC in February 2016 effective for April 2016 bills. Mississippi Attorney General Complaint 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 complaint is wide ranging and relates to tariffs and procedures under which Entergy Mississippi purchases power not generated in Mississippi to meet electricity demand. Entergy believes the complaint is unfounded. In December 2008 the defendant Entergy companies removed the Attorney General’s lawsuit to U.S. District Court in Jackson, Mississippi. The Mississippi attorney general moved to remand the matter to state court. In August 2012 the District Court issued an opinion denying the Attorney General’s motion for remand, finding that the District Court has subject matter jurisdiction under the Class Action Fairness Act. The defendant Entergy companies answered the complaint and filed a counterclaim for relief based upon the Mississippi Public Utilities Act and the Federal Power Act. In May 2009 the defendant Entergy companies filed a motion for judgment on the pleadings asserting grounds of federal preemption, the exclusive jurisdiction of the MPSC, and factual errors in the Attorney General’s complaint. In September 2012 the District Court heard oral argument on Entergy’s motion for judgment on the pleadings. In January 2014 the U.S. Supreme Court issued a decision in which it held that cases brought by attorneys general as the sole plaintiff to enforce state laws were not considered “mass actions” under the Class Action Fairness Act, so as to establish federal subject matter jurisdiction. One day later the Attorney General renewed his motion to remand the Entergy case back to state court, citing the U.S. Supreme Court’s decision. The defendant Entergy companies responded to that motion reiterating the additional grounds asserted for federal question jurisdiction, and the District Court held oral argument on the renewed motion to remand in February 2014. In April 2015 the District Court entered an order denying the renewed motion to remand, holding that the District Court has federal question subject matter jurisdiction. The Attorney General appealed to the U.S. Fifth Circuit Court of Appeals the denial of the motion to remand. In July 2015 the Fifth Circuit issued an order denying the appeal, and the Attorney General subsequently filed a petition for rehearing of the request for interlocutory appeal, which was also denied. In December 2015 the District Court ordered that the parties submit to the court undisputed and disputed facts that are material to the Entergy defendants’ motion for judgment on the pleadings, as well as supplemental briefs regarding the same. Those filings were made in January 2016. In September 2016 the Attorney General filed a mandamus petition with the U.S. Fifth Circuit Court of Appeals in which the Attorney General asked the Fifth Circuit to order the chief judge to reassign this case to another judge. The District Court denied the Entergy companies’ motion for judgment on the pleadings. The Entergy companies filed a motion seeking to amend the District Court’s order denying the Entergy companies’ motion for judgment on the pleadings and allowing an interlocutory appeal. The Fifth Circuit granted the Attorney General’s motion for writ of mandamus and directed the chief judge to assign the case to a new judge. The case has now been reassigned, and the Entergy companies’ motion to amend the order remains pending. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in the open 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 $10.9 million in 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. Both appeals are pending, but the appeals do not stay the PUCT’s decision. The federal appeal is scheduled to be heard in December 2016. In April 2016, Entergy Texas filed with the PUCT an application to refund to customers approximately $56.2 million . The refund resulted from (i) $41.8 million of fuel cost recovery over-collections through February 2016, (ii) the $10.9 million in bandwidth remedy payments, discussed above, that Entergy Texas received related to calendar year 2006 production costs, and (iii) $3.5 million in bandwidth remedy payments that Entergy Texas received related to 2006-2008 production costs. In June 2016, Entergy Texas filed an unopposed settlement agreement that added additional over-recovered fuel costs for the months of March and April 2016. The settlement resulted in a $68 million refund. The ALJ approved the refund on an interim basis to be made to most customers over a four-month period beginning with the first billing cycle of July 2016. In July 2016 the PUCT issued an order approving the interim refund. In July 2016, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period April 1, 2013 through March 31, 2016. Under a recent PUCT rule change, a fuel reconciliation is required to be filed at least once every three years and outside of a base rate case filing. During the reconciliation period, Entergy Texas incurred approximately $1.77 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimates an over-recovery balance of approximately $19.3 million , including interest, which Entergy Texas is requesting authority to carry over as the beginning balance for the subsequent reconciliation period beginning Apri1 2016. Entergy Texas also notes, however, that the $19.3 million over collection is currently being refunded to customers as a portion of the interim fuel refund beginning with the first billing cycle of July 2016, discussed above. Entergy Texas also is requesting a prudence finding for each of the fuel-related contracts and arrangements entered into or modified during the reconciliation period that have not been reviewed by the PUCT in a prior proceeding. The PUCT has one year to issue a final order in this proceeding. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC 2015 Rate Case In April 2015, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. The filing notified the APSC of Entergy Arkansas’s intent to implement a formula rate review mechanism pursuant to Arkansas legislation passed in 2015, and requested a retail rate increase of $268.4 million , with a net increase in revenue of $167 million. The filing requested a 10.2% return on common equity. In September 2015 the APSC staff and intervenors filed direct testimony, with the APSC staff recommending a revenue requirement of $217.9 million and a 9.65% return on common equity. In December 2015, Entergy Arkansas, the APSC staff, and certain of the intervenors in the rate case filed with the APSC a joint motion for approval of a settlement of the case that proposed a retail rate increase of approximately $225 million with a net increase in revenue of approximately $133 million ; an authorized return on common equity of 9.75% ; and a formula rate plan tariff that provides a +/- 50 basis point band around the 9.75% allowed return on common equity. A significant portion of the rate increase is related to Entergy Arkansas’s acquisition in March 2016 of Union Power Station Power Block 2 for a base purchase price of $237 million , subject to closing adjustments. The settlement agreement also provided for amortization over a 10-year period of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance. A settlement hearing was held in January 2016. In February 2016 the APSC approved the settlement with one exception that would reduce the retail rate increase proposed in the settlement by $5 million . The settling parties agreed to the APSC modifications in February 2016. The new rates were effective February 24, 2016 and began billing with the first billing cycle of April 2016. In March 2016, Entergy Arkansas made a compliance filing regarding the new rates that included an interim base rate adjustment surcharge, effective with the first billing cycle of April 2016, to recover the incremental revenue requirement for the period February 24, 2016 through March 31, 2016. The interim base rate adjustment surcharge will recover a total of $21.1 million over the nine-month period from April 2016 through December 2016. 2016 Formula Rate Plan Filing In July 2016, Entergy Arkansas filed with the APSC its 2016 formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2017 test period to be below the formula rate plan bandwidth. The filing requested a $67.7 million revenue requirement increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . In October 2016, Entergy Arkansas filed with the APSC revised formula rate plan attachments with an updated request for a $54.4 million revenue requirement increase based on acceptance of certain adjustments and recommendations made by the APSC staff and other intervenors, as well as three additional adjustments identified as appropriate by Entergy Arkansas. Also in October 2016, Entergy Arkansas and all parties filed a joint motion to approve a settlement agreement and waive the hearing scheduled for November 2016. The APSC denied the request to waive the hearing, directed certain witnesses to appear, and stated that approval of the settlement agreement would be addressed by a subsequent order. In November 2016 a hearing was held and the APSC issued an order directing the parties to brief certain issues. The parties to the settlement agreement, who reached agreement on all issues and certain additional provisions related to future filing information, requested an order approving the settlement agreement and the proposed $54.4 million revenue requirement increase and rate adjustment by December 9, 2016. If a final order is not issued by this date, the proposed formula rate plan rate adjustment will become effective December 30, 2016, subject to refund. Advanced Metering Infrastructure (AMI) Filing In September 2016, Entergy Arkansas filed an application seeking an order from the APSC finding that Entergy Arkansas’s deployment of AMI is in the public interest. Entergy Arkansas proposed to replace existing meters with advanced meters that enable two-way data communication; design and build a secure and reliable network to support such communications; and implement support systems. AMI is intended to serve as the foundation of Entergy Arkansas’s modernized power grid. The filing identified a number quantified and unquantified benefits, and Entergy Arkansas provided a cost benefit analysis showing that its AMI deployment is expected to produce a nominal net benefit to customers of $431 million . Entergy Arkansas also sought to continue to include in rate base the remaining book value, approximately $57 million , of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Entergy Arkansas proposed a 15-year depreciable life for the new advanced meters, the three-year deployment of which is expected to begin in 2019. Subject to approval by the APSC, deployment of the communications network is expected to begin in 2018. Entergy Arkansas proposed to include the AMI deployment costs and the quantified benefits in future formula rate plan filings. In order to have certainty around its 2018 projected AMI deployment costs, Entergy Arkansas sought an order from the APSC prior to the hearing on its expected 2017 formula rate plan filing in fourth quarter 2017. Filings with the LPSC Retail Rates - Electric 2015 Formula Rate Plan Filing In May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. The evaluation report reflects an earned return on common equity of 9.07% . As such, no adjustment to base formula rate plan revenue is required. The following other adjustments, however, are required under the formula rate plan: an increase in the legacy Entergy Louisiana additional capacity mechanism of $14.2 million ; a separate increase in legacy Entergy Louisiana revenue of $10 million primarily to reflect the effects of the termination of the System Agreement; an increase in the legacy Entergy Gulf States Louisiana additional capacity mechanism of $0.5 million ; a decrease in legacy Entergy Gulf States Louisiana revenue of $58.7 million primarily to reflect the effects of the termination of the System Agreement; and an increase of $11 million to the MISO cost recovery mechanism. Rates were implemented with the first billing cycle of September 2016, subject to refund. Waterford 3 Replacement Steam Generator Project Following the completion of the Waterford 3 replacement steam generator project, the LPSC undertook a prudence review in connection with a filing made by Entergy Louisiana in April 2013 with regard to the following aspects of the replacement project: 1) project management; 2) cost controls; 3) success in achieving stated objectives; 4) the costs of the replacement project; and 5) the outage length and replacement power costs. In July 2014 the LPSC Staff filed testimony recommending potential project and replacement power cost disallowances of up to $71 million , citing a need for further explanation or documentation from Entergy Louisiana. An intervenor filed testimony recommending disallowance of $141 million of incremental project costs, claiming the steam generator fabricator was imprudent. Entergy Louisiana provided further documentation and explanation requested by the LPSC staff. An evidentiary hearing was held in December 2014. At the hearing the parties maintained the positions reflected in pre-filed testimony. Entergy Louisiana believes that the replacement steam generator costs were prudently incurred and applicable legal principles support their recovery in rates. Nevertheless, Entergy Louisiana recorded a write-off of $16 million of Waterford 3’s plant balance in December 2014 because of the uncertainty at the time associated with the resolution of the prudence review. In December 2015 the ALJ issued a proposed recommendation, which was subsequently finalized, concluding that Entergy Louisiana prudently managed the Waterford 3 replacement steam generator project, including the selection, use, and oversight of contractors, and could not reasonably have anticipated the damage to the steam generators. Nevertheless, the ALJ concluded that Entergy Louisiana was liable for the conduct of its contractor and subcontractor and, therefore, recommended a disallowance of $67 million in capital costs. Additionally, the ALJ concluded that Entergy Louisiana did not sufficiently justify the incurrence of $2 million in replacement power costs during the replacement outage. After considering the progress of the proceeding in light of the ALJ recommendation, Entergy Louisiana recorded in the fourth quarter 2015 approximately $77 million in charges, including a $45 million asset write-off and a $32 million regulatory charge, to reflect that a portion of the assets associated with the Waterford 3 replacement steam generator project is no longer probable of recovery. Entergy Louisiana maintains that the ALJ’s recommendation contains significant factual and legal errors. In October 2016 the parties reached a settlement in this matter. If approved by the LPSC, the settlement effectively would provide for an agreed-upon disallowance of $67 million of plant, which had been previously written off by Entergy Louisiana, as discussed above. The settlement would also require a refund to customers of approximately $43 million , representing the revenues previously collected associated with the disallowed plant, including interest, and $2 million of replacement power costs. Entergy Louisiana had previously recorded provisions for these refunds. Additionally, under the settlement, Entergy Louisiana would provide a one-time credit to customers of approximately $24 million , representing the value of potential future service credits agreed to by the project contractor. The settlement provides that Entergy Louisiana can retain the value associated with these service credits, to the extent they are realized in the future. If the settlement is approved by the LPSC, the refunds and one-time credit to customers would be made in December 2016. Ninemile 6 As discussed in the Form 10-K, in July 2015, Entergy Louisiana submitted to the LPSC a Ninemile 6 compliance filing including an estimate at completion, inclusive of interconnection costs and transmission upgrades, of approximately $648 million , or $76 million less than originally estimated, along with other project details and supporting evidence, to enable the LPSC to review the prudence of Entergy Louisiana’s management of the project. Testimony filed by the LPSC staff generally supports the prudence of the management of the project and recovery of the costs incurred to complete the project. The LPSC staff had questioned the warranty coverage for one element of the project. In March 2016, Entergy Louisiana and the LPSC staff filed a joint motion to suspend the procedural schedule pending the filing of an uncontested joint stipulated settlement. In October 2016 all parties agreed to a stipulation providing that 100% of Ninemile 6 construction costs was prudently incurred and is eligible for recovery from customers, but reserving the LPSC’s rights to review the prudence of Entergy Louisiana’s actions regarding one element of the project. This stipulation is subject to LPSC approval. Union Power Station As discussed in the Form 10-K, in October 2015 the LPSC approved a settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station. In March 2016, Entergy Louisiana acquired Power Blocks 3 and 4 of Union Power Station for an aggregate purchase price of approximately $474 million and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. 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. Parties have requested further proceedings on the prudence of Entergy Louisiana’s decision to deactivate Willow Glen 2 and 4. This matter is pending before an ALJ, and a hearing has been scheduled in March 2017 to determine, under applicable law, whether Willow Glen 2 and 4 units should be returned to service. Retail Rates - Gas In January 2016, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2015. The filing showed an earned return on common equity of 10.22% , which is within the authorized bandwidth, therefore requiring no change in rates. In March 2016 the LPSC staff issued its report stating that the 2015 gas rate stabilization plan filing is in compliance with the exception of several issues that require additional information, explanation, or clarification for which the LPSC staff has reserved the right to further review. In July 2016 the parties to the proceeding filed an unopposed joint report and motion for entry of order accepting report that indicates no outstanding issues remain in the filing. Absent approval of an extension by the LPSC, test year 2015 is the final year under the current gas rate stabilization plan. In February 2016, however, Entergy Louisiana filed a motion requesting to extend the term of the gas rate stabilization plan for an additional three-year term. A procedural schedule has been established, including a hearing in November 2016. The LPSC staff filed testimony supportive of the renewal of the gas rate stabilization plan. The parties submitted a motion indicating that they are working toward development of a settlement that they would seek to have approved at the November 2016 hearing. Filings with the MPSC In March 2016, Entergy Mississippi submitted its formula rate plan 2016 test year filing showing Entergy Mississippi’s projected earned return for the 2016 calendar year to be below the formula rate plan bandwidth. The filing showed a $32.6 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 9.96% , within the formula rate plan bandwidth. In June 2016 the MPSC approved Entergy Mississippi’s joint stipulation with the Mississippi Public Utilities Staff. The joint stipulation provided for a total revenue increase of $23.7 million . The revenue increase includes a $19.4 million increase through the formula rate plan, resulting in a return on common equity point of adjustment of 10.07% . The revenue increase also includes $4.3 million in incremental ad valorem tax expenses to be collected through an updated ad valorem tax adjustment rider. The revenue increase and ad valorem tax adjustment rider were effective with the July 2016 bills. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the terms of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6, the revenue requirement associated with the purchase of Power Block 1 of the Union Power Station, and a credit to customers of $400 thousand monthly beginning June 2016 in recognition of the decrease in other operation and maintenance expenses that would result with the deactivation of Michoud Units 2 and 3. In March 2016, Entergy New Orleans purchased Power Block 1 of the Union Power Station for approximately $237 million and initiated recovery of these costs with March 2016 bills. In July 2016, Entergy New Orleans and the City Council Utility Committee agreed to a temporary increase in the Michoud credit to customers to a total of $1.4 million monthly for August 2016 through December 2016. Internal Restructuring In July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring which would result in the transfer of substantially all of the assets and operations of Entergy New Orleans to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval of the City Council and the FERC. The application provided that if it is approved by the City Council in 2016, Entergy New Orleans would credit retail customers $5 million in each of the years 2016 and 2017. Intervenors filed direct testimony and comments in September 2016 and the City Council advisors filed direct testimony in October 2016. A hearing at the City Council scheduled for October 2016 has been continued until December 2016. In October 2016, Entergy New Orleans filed its rebuttal testimony and therein agreed that, given the extended procedural schedule, the $5 million in proposed 2016 credits would still be paid, although on a different schedule, if the City Council approved the restructuring after 2016 but before the end of the first quarter of 2017. The filing with the FERC has not yet been made, but if the restructuring is approved by the FERC by December 31, 2018, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2018, 2019, and 2020. If City Council and FERC approvals are obtained, Entergy New Orleans expects the restructuring will be consummated by December 31, 2017. It is currently contemplated that Entergy New Orleans would undertake a multi-step restructuring, which would include the following: • Entergy New Orleans would redeem its outstanding preferred stock at a price of approximately $21 million , which includes an expected call premium of approximately $819,000 , plus any accumulated and unpaid dividends. • Entergy New Orleans would convert from a Louisiana corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy New Orleans will allocate substantially all of its assets to a new subsidiary, Entergy New Orleans Power, LLC, a Texas limited liability company (Entergy New Orleans Power), and Entergy New Orleans Power will assume substantially all of the liabilities of Entergy New Orleans, in a transaction regarded as a merger under the TXBOC. Entergy New Orleans will remain in existence and hold the membership interests in Entergy New Orleans Power. • Entergy New Orleans will contribute the membership interests in Entergy New Orleans Power to an affiliate (Entergy Utility Holding Company, LLC
Entergy New Orleans [Member]
Public Utilities Disclosure [Text Block]	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2016, Entergy Arkansas filed its annual rate redetermination pursuant to the production cost allocation rider, which reflected recovery of the production cost allocation rider true-up adjustment of the 2014 and 2015 unrecovered retail balance in the amount of $1.9 million . Additionally, the redetermined rates reflected the recovery of a $1.9 million System Agreement bandwidth remedy payment resulting from a compliance filing pursuant to the FERC’s December 2015 order related to test year 2009 production costs. The rates for the 2016 production cost allocation rider update became effective with the first billing cycle of July 2016, and rates will be effective through June 2017. Entergy Louisiana In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. The LPSC staff issued its audit report in January 2013. The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million , plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates. The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing. Two parties intervened in the proceeding. A procedural schedule was established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC staff report and any issues raised by intervenors. One intervenor sought further proceedings regarding certain issues it raised in its comments on the LPSC staff report. Entergy Louisiana filed responses to both the LPSC staff report and the issues raised by the intervenor. After conducting additional discovery, in April 2016 the LPSC staff consultant issued its supplemental audit report, which concluded that Entergy Louisiana was not imprudent on the issues raised by the intervenor. The intervenor has stated that it does not intend to pursue these issues further. In October 2016 the LPSC staff filed testimony affirming the recommendation in its audit report that nuclear dry fuel storage costs should be realigned to base rates. A procedural schedule has been established for this proceeding, including an evidentiary hearing in November 2016. In December 2011 the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through 2009. In March 2016 the LPSC staff consultant issued its audit report. In its report, the LPSC staff consultant recommended that Entergy Louisiana refund approximately $8.6 million , plus interest, to customers and realign the recovery of approximately $12.7 million from Entergy Gulf States Louisiana’s fuel adjustment clause to base rates. In September 2016 the LPSC staff filed testimony stating that is was no longer recommending a disallowance of $3.4 million of the $8.6 million discussed above, but otherwise maintained positions from its report. Entergy Louisiana has recorded a provision for the estimated outcome of this proceeding. A procedural schedule has been established for this proceeding, including a hearing in December 2016. In June 2016 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. In recognition of the business combination that occurred in 2015, the audit notice was issued to Entergy Louisiana and will also include a review of charges to legacy Entergy Gulf States Louisiana customers prior to the business combination. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment and purchased gas adjustment mechanisms for the period from 2012 through 2015. Discovery has not commenced. Entergy Mississippi Entergy Mississippi had a deferred fuel over-recovery balance of $58.3 million as of May 31, 2015, along with an under-recovery balance of $12.3 million under the power management rider. Pursuant to those tariffs, in July 2015, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider to flow through to customers the approximately $46 million net over-recovery over a six-month period. In August 2015 the MPSC approved the interim adjustments effective with September 2015 bills. In November 2015, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included a projected over-recovery balance of $48 million projected through January 31, 2016. In January 2016 the MPSC approved the redetermined annual factor effective February 1, 2016. The MPSC further ordered, however, that due to the significant change in natural gas price forecasts since Entergy Mississippi’s filing in November 2015, Entergy Mississippi shall file a revised fuel factor with the MPSC no later than February 1, 2016. Pursuant to that order, Entergy Mississippi submitted a revised fuel factor. Additionally, because Entergy Mississippi’s projected over-recovery balance for the period ending January 31, 2017 was $68 million , in February 2016, Entergy Mississippi filed for another interim adjustment to the energy cost factor effective April 2016 to flow through to customers the projected over-recovery balance over a six-month period. That interim adjustment was approved by the MPSC in February 2016 effective for April 2016 bills. Mississippi Attorney General Complaint 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 complaint is wide ranging and relates to tariffs and procedures under which Entergy Mississippi purchases power not generated in Mississippi to meet electricity demand. Entergy believes the complaint is unfounded. In December 2008 the defendant Entergy companies removed the Attorney General’s lawsuit to U.S. District Court in Jackson, Mississippi. The Mississippi attorney general moved to remand the matter to state court. In August 2012 the District Court issued an opinion denying the Attorney General’s motion for remand, finding that the District Court has subject matter jurisdiction under the Class Action Fairness Act. The defendant Entergy companies answered the complaint and filed a counterclaim for relief based upon the Mississippi Public Utilities Act and the Federal Power Act. In May 2009 the defendant Entergy companies filed a motion for judgment on the pleadings asserting grounds of federal preemption, the exclusive jurisdiction of the MPSC, and factual errors in the Attorney General’s complaint. In September 2012 the District Court heard oral argument on Entergy’s motion for judgment on the pleadings. In January 2014 the U.S. Supreme Court issued a decision in which it held that cases brought by attorneys general as the sole plaintiff to enforce state laws were not considered “mass actions” under the Class Action Fairness Act, so as to establish federal subject matter jurisdiction. One day later the Attorney General renewed his motion to remand the Entergy case back to state court, citing the U.S. Supreme Court’s decision. The defendant Entergy companies responded to that motion reiterating the additional grounds asserted for federal question jurisdiction, and the District Court held oral argument on the renewed motion to remand in February 2014. In April 2015 the District Court entered an order denying the renewed motion to remand, holding that the District Court has federal question subject matter jurisdiction. The Attorney General appealed to the U.S. Fifth Circuit Court of Appeals the denial of the motion to remand. In July 2015 the Fifth Circuit issued an order denying the appeal, and the Attorney General subsequently filed a petition for rehearing of the request for interlocutory appeal, which was also denied. In December 2015 the District Court ordered that the parties submit to the court undisputed and disputed facts that are material to the Entergy defendants’ motion for judgment on the pleadings, as well as supplemental briefs regarding the same. Those filings were made in January 2016. In September 2016 the Attorney General filed a mandamus petition with the U.S. Fifth Circuit Court of Appeals in which the Attorney General asked the Fifth Circuit to order the chief judge to reassign this case to another judge. The District Court denied the Entergy companies’ motion for judgment on the pleadings. The Entergy companies filed a motion seeking to amend the District Court’s order denying the Entergy companies’ motion for judgment on the pleadings and allowing an interlocutory appeal. The Fifth Circuit granted the Attorney General’s motion for writ of mandamus and directed the chief judge to assign the case to a new judge. The case has now been reassigned, and the Entergy companies’ motion to amend the order remains pending. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in the open 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 $10.9 million in 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. Both appeals are pending, but the appeals do not stay the PUCT’s decision. The federal appeal is scheduled to be heard in December 2016. In April 2016, Entergy Texas filed with the PUCT an application to refund to customers approximately $56.2 million . The refund resulted from (i) $41.8 million of fuel cost recovery over-collections through February 2016, (ii) the $10.9 million in bandwidth remedy payments, discussed above, that Entergy Texas received related to calendar year 2006 production costs, and (iii) $3.5 million in bandwidth remedy payments that Entergy Texas received related to 2006-2008 production costs. In June 2016, Entergy Texas filed an unopposed settlement agreement that added additional over-recovered fuel costs for the months of March and April 2016. The settlement resulted in a $68 million refund. The ALJ approved the refund on an interim basis to be made to most customers over a four-month period beginning with the first billing cycle of July 2016. In July 2016 the PUCT issued an order approving the interim refund. In July 2016, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period April 1, 2013 through March 31, 2016. Under a recent PUCT rule change, a fuel reconciliation is required to be filed at least once every three years and outside of a base rate case filing. During the reconciliation period, Entergy Texas incurred approximately $1.77 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimates an over-recovery balance of approximately $19.3 million , including interest, which Entergy Texas is requesting authority to carry over as the beginning balance for the subsequent reconciliation period beginning Apri1 2016. Entergy Texas also notes, however, that the $19.3 million over collection is currently being refunded to customers as a portion of the interim fuel refund beginning with the first billing cycle of July 2016, discussed above. Entergy Texas also is requesting a prudence finding for each of the fuel-related contracts and arrangements entered into or modified during the reconciliation period that have not been reviewed by the PUCT in a prior proceeding. The PUCT has one year to issue a final order in this proceeding. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC 2015 Rate Case In April 2015, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. The filing notified the APSC of Entergy Arkansas’s intent to implement a formula rate review mechanism pursuant to Arkansas legislation passed in 2015, and requested a retail rate increase of $268.4 million , with a net increase in revenue of $167 million. The filing requested a 10.2% return on common equity. In September 2015 the APSC staff and intervenors filed direct testimony, with the APSC staff recommending a revenue requirement of $217.9 million and a 9.65% return on common equity. In December 2015, Entergy Arkansas, the APSC staff, and certain of the intervenors in the rate case filed with the APSC a joint motion for approval of a settlement of the case that proposed a retail rate increase of approximately $225 million with a net increase in revenue of approximately $133 million ; an authorized return on common equity of 9.75% ; and a formula rate plan tariff that provides a +/- 50 basis point band around the 9.75% allowed return on common equity. A significant portion of the rate increase is related to Entergy Arkansas’s acquisition in March 2016 of Union Power Station Power Block 2 for a base purchase price of $237 million , subject to closing adjustments. The settlement agreement also provided for amortization over a 10-year period of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance. A settlement hearing was held in January 2016. In February 2016 the APSC approved the settlement with one exception that would reduce the retail rate increase proposed in the settlement by $5 million . The settling parties agreed to the APSC modifications in February 2016. The new rates were effective February 24, 2016 and began billing with the first billing cycle of April 2016. In March 2016, Entergy Arkansas made a compliance filing regarding the new rates that included an interim base rate adjustment surcharge, effective with the first billing cycle of April 2016, to recover the incremental revenue requirement for the period February 24, 2016 through March 31, 2016. The interim base rate adjustment surcharge will recover a total of $21.1 million over the nine-month period from April 2016 through December 2016. 2016 Formula Rate Plan Filing In July 2016, Entergy Arkansas filed with the APSC its 2016 formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2017 test period to be below the formula rate plan bandwidth. The filing requested a $67.7 million revenue requirement increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . In October 2016, Entergy Arkansas filed with the APSC revised formula rate plan attachments with an updated request for a $54.4 million revenue requirement increase based on acceptance of certain adjustments and recommendations made by the APSC staff and other intervenors, as well as three additional adjustments identified as appropriate by Entergy Arkansas. Also in October 2016, Entergy Arkansas and all parties filed a joint motion to approve a settlement agreement and waive the hearing scheduled for November 2016. The APSC denied the request to waive the hearing, directed certain witnesses to appear, and stated that approval of the settlement agreement would be addressed by a subsequent order. In November 2016 a hearing was held and the APSC issued an order directing the parties to brief certain issues. The parties to the settlement agreement, who reached agreement on all issues and certain additional provisions related to future filing information, requested an order approving the settlement agreement and the proposed $54.4 million revenue requirement increase and rate adjustment by December 9, 2016. If a final order is not issued by this date, the proposed formula rate plan rate adjustment will become effective December 30, 2016, subject to refund. Advanced Metering Infrastructure (AMI) Filing In September 2016, Entergy Arkansas filed an application seeking an order from the APSC finding that Entergy Arkansas’s deployment of AMI is in the public interest. Entergy Arkansas proposed to replace existing meters with advanced meters that enable two-way data communication; design and build a secure and reliable network to support such communications; and implement support systems. AMI is intended to serve as the foundation of Entergy Arkansas’s modernized power grid. The filing identified a number quantified and unquantified benefits, and Entergy Arkansas provided a cost benefit analysis showing that its AMI deployment is expected to produce a nominal net benefit to customers of $431 million . Entergy Arkansas also sought to continue to include in rate base the remaining book value, approximately $57 million , of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Entergy Arkansas proposed a 15-year depreciable life for the new advanced meters, the three-year deployment of which is expected to begin in 2019. Subject to approval by the APSC, deployment of the communications network is expected to begin in 2018. Entergy Arkansas proposed to include the AMI deployment costs and the quantified benefits in future formula rate plan filings. In order to have certainty around its 2018 projected AMI deployment costs, Entergy Arkansas sought an order from the APSC prior to the hearing on its expected 2017 formula rate plan filing in fourth quarter 2017. Filings with the LPSC Retail Rates - Electric 2015 Formula Rate Plan Filing In May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. The evaluation report reflects an earned return on common equity of 9.07% . As such, no adjustment to base formula rate plan revenue is required. The following other adjustments, however, are required under the formula rate plan: an increase in the legacy Entergy Louisiana additional capacity mechanism of $14.2 million ; a separate increase in legacy Entergy Louisiana revenue of $10 million primarily to reflect the effects of the termination of the System Agreement; an increase in the legacy Entergy Gulf States Louisiana additional capacity mechanism of $0.5 million ; a decrease in legacy Entergy Gulf States Louisiana revenue of $58.7 million primarily to reflect the effects of the termination of the System Agreement; and an increase of $11 million to the MISO cost recovery mechanism. Rates were implemented with the first billing cycle of September 2016, subject to refund. Waterford 3 Replacement Steam Generator Project Following the completion of the Waterford 3 replacement steam generator project, the LPSC undertook a prudence review in connection with a filing made by Entergy Louisiana in April 2013 with regard to the following aspects of the replacement project: 1) project management; 2) cost controls; 3) success in achieving stated objectives; 4) the costs of the replacement project; and 5) the outage length and replacement power costs. In July 2014 the LPSC Staff filed testimony recommending potential project and replacement power cost disallowances of up to $71 million , citing a need for further explanation or documentation from Entergy Louisiana. An intervenor filed testimony recommending disallowance of $141 million of incremental project costs, claiming the steam generator fabricator was imprudent. Entergy Louisiana provided further documentation and explanation requested by the LPSC staff. An evidentiary hearing was held in December 2014. At the hearing the parties maintained the positions reflected in pre-filed testimony. Entergy Louisiana believes that the replacement steam generator costs were prudently incurred and applicable legal principles support their recovery in rates. Nevertheless, Entergy Louisiana recorded a write-off of $16 million of Waterford 3’s plant balance in December 2014 because of the uncertainty at the time associated with the resolution of the prudence review. In December 2015 the ALJ issued a proposed recommendation, which was subsequently finalized, concluding that Entergy Louisiana prudently managed the Waterford 3 replacement steam generator project, including the selection, use, and oversight of contractors, and could not reasonably have anticipated the damage to the steam generators. Nevertheless, the ALJ concluded that Entergy Louisiana was liable for the conduct of its contractor and subcontractor and, therefore, recommended a disallowance of $67 million in capital costs. Additionally, the ALJ concluded that Entergy Louisiana did not sufficiently justify the incurrence of $2 million in replacement power costs during the replacement outage. After considering the progress of the proceeding in light of the ALJ recommendation, Entergy Louisiana recorded in the fourth quarter 2015 approximately $77 million in charges, including a $45 million asset write-off and a $32 million regulatory charge, to reflect that a portion of the assets associated with the Waterford 3 replacement steam generator project is no longer probable of recovery. Entergy Louisiana maintains that the ALJ’s recommendation contains significant factual and legal errors. In October 2016 the parties reached a settlement in this matter. If approved by the LPSC, the settlement effectively would provide for an agreed-upon disallowance of $67 million of plant, which had been previously written off by Entergy Louisiana, as discussed above. The settlement would also require a refund to customers of approximately $43 million , representing the revenues previously collected associated with the disallowed plant, including interest, and $2 million of replacement power costs. Entergy Louisiana had previously recorded provisions for these refunds. Additionally, under the settlement, Entergy Louisiana would provide a one-time credit to customers of approximately $24 million , representing the value of potential future service credits agreed to by the project contractor. The settlement provides that Entergy Louisiana can retain the value associated with these service credits, to the extent they are realized in the future. If the settlement is approved by the LPSC, the refunds and one-time credit to customers would be made in December 2016. Ninemile 6 As discussed in the Form 10-K, in July 2015, Entergy Louisiana submitted to the LPSC a Ninemile 6 compliance filing including an estimate at completion, inclusive of interconnection costs and transmission upgrades, of approximately $648 million , or $76 million less than originally estimated, along with other project details and supporting evidence, to enable the LPSC to review the prudence of Entergy Louisiana’s management of the project. Testimony filed by the LPSC staff generally supports the prudence of the management of the project and recovery of the costs incurred to complete the project. The LPSC staff had questioned the warranty coverage for one element of the project. In March 2016, Entergy Louisiana and the LPSC staff filed a joint motion to suspend the procedural schedule pending the filing of an uncontested joint stipulated settlement. In October 2016 all parties agreed to a stipulation providing that 100% of Ninemile 6 construction costs was prudently incurred and is eligible for recovery from customers, but reserving the LPSC’s rights to review the prudence of Entergy Louisiana’s actions regarding one element of the project. This stipulation is subject to LPSC approval. Union Power Station As discussed in the Form 10-K, in October 2015 the LPSC approved a settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station. In March 2016, Entergy Louisiana acquired Power Blocks 3 and 4 of Union Power Station for an aggregate purchase price of approximately $474 million and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. 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. Parties have requested further proceedings on the prudence of Entergy Louisiana’s decision to deactivate Willow Glen 2 and 4. This matter is pending before an ALJ, and a hearing has been scheduled in March 2017 to determine, under applicable law, whether Willow Glen 2 and 4 units should be returned to service. Retail Rates - Gas In January 2016, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2015. The filing showed an earned return on common equity of 10.22% , which is within the authorized bandwidth, therefore requiring no change in rates. In March 2016 the LPSC staff issued its report stating that the 2015 gas rate stabilization plan filing is in compliance with the exception of several issues that require additional information, explanation, or clarification for which the LPSC staff has reserved the right to further review. In July 2016 the parties to the proceeding filed an unopposed joint report and motion for entry of order accepting report that indicates no outstanding issues remain in the filing. Absent approval of an extension by the LPSC, test year 2015 is the final year under the current gas rate stabilization plan. In February 2016, however, Entergy Louisiana filed a motion requesting to extend the term of the gas rate stabilization plan for an additional three-year term. A procedural schedule has been established, including a hearing in November 2016. The LPSC staff filed testimony supportive of the renewal of the gas rate stabilization plan. The parties submitted a motion indicating that they are working toward development of a settlement that they would seek to have approved at the November 2016 hearing. Filings with the MPSC In March 2016, Entergy Mississippi submitted its formula rate plan 2016 test year filing showing Entergy Mississippi’s projected earned return for the 2016 calendar year to be below the formula rate plan bandwidth. The filing showed a $32.6 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 9.96% , within the formula rate plan bandwidth. In June 2016 the MPSC approved Entergy Mississippi’s joint stipulation with the Mississippi Public Utilities Staff. The joint stipulation provided for a total revenue increase of $23.7 million . The revenue increase includes a $19.4 million increase through the formula rate plan, resulting in a return on common equity point of adjustment of 10.07% . The revenue increase also includes $4.3 million in incremental ad valorem tax expenses to be collected through an updated ad valorem tax adjustment rider. The revenue increase and ad valorem tax adjustment rider were effective with the July 2016 bills. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the terms of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6, the revenue requirement associated with the purchase of Power Block 1 of the Union Power Station, and a credit to customers of $400 thousand monthly beginning June 2016 in recognition of the decrease in other operation and maintenance expenses that would result with the deactivation of Michoud Units 2 and 3. In March 2016, Entergy New Orleans purchased Power Block 1 of the Union Power Station for approximately $237 million and initiated recovery of these costs with March 2016 bills. In July 2016, Entergy New Orleans and the City Council Utility Committee agreed to a temporary increase in the Michoud credit to customers to a total of $1.4 million monthly for August 2016 through December 2016. Internal Restructuring In July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring which would result in the transfer of substantially all of the assets and operations of Entergy New Orleans to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval of the City Council and the FERC. The application provided that if it is approved by the City Council in 2016, Entergy New Orleans would credit retail customers $5 million in each of the years 2016 and 2017. Intervenors filed direct testimony and comments in September 2016 and the City Council advisors filed direct testimony in October 2016. A hearing at the City Council scheduled for October 2016 has been continued until December 2016. In October 2016, Entergy New Orleans filed its rebuttal testimony and therein agreed that, given the extended procedural schedule, the $5 million in proposed 2016 credits would still be paid, although on a different schedule, if the City Council approved the restructuring after 2016 but before the end of the first quarter of 2017. The filing with the FERC has not yet been made, but if the restructuring is approved by the FERC by December 31, 2018, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2018, 2019, and 2020. If City Council and FERC approvals are obtained, Entergy New Orleans expects the restructuring will be consummated by December 31, 2017. It is currently contemplated that Entergy New Orleans would undertake a multi-step restructuring, which would include the following: • Entergy New Orleans would redeem its outstanding preferred stock at a price of approximately $21 million , which includes an expected call premium of approximately $819,000 , plus any accumulated and unpaid dividends. • Entergy New Orleans would convert from a Louisiana corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy New Orleans will allocate substantially all of its assets to a new subsidiary, Entergy New Orleans Power, LLC, a Texas limited liability company (Entergy New Orleans Power), and Entergy New Orleans Power will assume substantially all of the liabilities of Entergy New Orleans, in a transaction regarded as a merger under the TXBOC. Entergy New Orleans will remain in existence and hold the membership interests in Entergy New Orleans Power. • Entergy New Orleans will contribute the membership interests in Entergy New Orleans Power to an affiliate (Entergy Utility Holding Company, LLC
Entergy Texas [Member]
Public Utilities Disclosure [Text Block]	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2016, Entergy Arkansas filed its annual rate redetermination pursuant to the production cost allocation rider, which reflected recovery of the production cost allocation rider true-up adjustment of the 2014 and 2015 unrecovered retail balance in the amount of $1.9 million . Additionally, the redetermined rates reflected the recovery of a $1.9 million System Agreement bandwidth remedy payment resulting from a compliance filing pursuant to the FERC’s December 2015 order related to test year 2009 production costs. The rates for the 2016 production cost allocation rider update became effective with the first billing cycle of July 2016, and rates will be effective through June 2017. Entergy Louisiana In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. The LPSC staff issued its audit report in January 2013. The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million , plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates. The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing. Two parties intervened in the proceeding. A procedural schedule was established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC staff report and any issues raised by intervenors. One intervenor sought further proceedings regarding certain issues it raised in its comments on the LPSC staff report. Entergy Louisiana filed responses to both the LPSC staff report and the issues raised by the intervenor. After conducting additional discovery, in April 2016 the LPSC staff consultant issued its supplemental audit report, which concluded that Entergy Louisiana was not imprudent on the issues raised by the intervenor. The intervenor has stated that it does not intend to pursue these issues further. In October 2016 the LPSC staff filed testimony affirming the recommendation in its audit report that nuclear dry fuel storage costs should be realigned to base rates. A procedural schedule has been established for this proceeding, including an evidentiary hearing in November 2016. In December 2011 the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through 2009. In March 2016 the LPSC staff consultant issued its audit report. In its report, the LPSC staff consultant recommended that Entergy Louisiana refund approximately $8.6 million , plus interest, to customers and realign the recovery of approximately $12.7 million from Entergy Gulf States Louisiana’s fuel adjustment clause to base rates. In September 2016 the LPSC staff filed testimony stating that is was no longer recommending a disallowance of $3.4 million of the $8.6 million discussed above, but otherwise maintained positions from its report. Entergy Louisiana has recorded a provision for the estimated outcome of this proceeding. A procedural schedule has been established for this proceeding, including a hearing in December 2016. In June 2016 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. In recognition of the business combination that occurred in 2015, the audit notice was issued to Entergy Louisiana and will also include a review of charges to legacy Entergy Gulf States Louisiana customers prior to the business combination. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment and purchased gas adjustment mechanisms for the period from 2012 through 2015. Discovery has not commenced. Entergy Mississippi Entergy Mississippi had a deferred fuel over-recovery balance of $58.3 million as of May 31, 2015, along with an under-recovery balance of $12.3 million under the power management rider. Pursuant to those tariffs, in July 2015, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider to flow through to customers the approximately $46 million net over-recovery over a six-month period. In August 2015 the MPSC approved the interim adjustments effective with September 2015 bills. In November 2015, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included a projected over-recovery balance of $48 million projected through January 31, 2016. In January 2016 the MPSC approved the redetermined annual factor effective February 1, 2016. The MPSC further ordered, however, that due to the significant change in natural gas price forecasts since Entergy Mississippi’s filing in November 2015, Entergy Mississippi shall file a revised fuel factor with the MPSC no later than February 1, 2016. Pursuant to that order, Entergy Mississippi submitted a revised fuel factor. Additionally, because Entergy Mississippi’s projected over-recovery balance for the period ending January 31, 2017 was $68 million , in February 2016, Entergy Mississippi filed for another interim adjustment to the energy cost factor effective April 2016 to flow through to customers the projected over-recovery balance over a six-month period. That interim adjustment was approved by the MPSC in February 2016 effective for April 2016 bills. Mississippi Attorney General Complaint 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 complaint is wide ranging and relates to tariffs and procedures under which Entergy Mississippi purchases power not generated in Mississippi to meet electricity demand. Entergy believes the complaint is unfounded. In December 2008 the defendant Entergy companies removed the Attorney General’s lawsuit to U.S. District Court in Jackson, Mississippi. The Mississippi attorney general moved to remand the matter to state court. In August 2012 the District Court issued an opinion denying the Attorney General’s motion for remand, finding that the District Court has subject matter jurisdiction under the Class Action Fairness Act. The defendant Entergy companies answered the complaint and filed a counterclaim for relief based upon the Mississippi Public Utilities Act and the Federal Power Act. In May 2009 the defendant Entergy companies filed a motion for judgment on the pleadings asserting grounds of federal preemption, the exclusive jurisdiction of the MPSC, and factual errors in the Attorney General’s complaint. In September 2012 the District Court heard oral argument on Entergy’s motion for judgment on the pleadings. In January 2014 the U.S. Supreme Court issued a decision in which it held that cases brought by attorneys general as the sole plaintiff to enforce state laws were not considered “mass actions” under the Class Action Fairness Act, so as to establish federal subject matter jurisdiction. One day later the Attorney General renewed his motion to remand the Entergy case back to state court, citing the U.S. Supreme Court’s decision. The defendant Entergy companies responded to that motion reiterating the additional grounds asserted for federal question jurisdiction, and the District Court held oral argument on the renewed motion to remand in February 2014. In April 2015 the District Court entered an order denying the renewed motion to remand, holding that the District Court has federal question subject matter jurisdiction. The Attorney General appealed to the U.S. Fifth Circuit Court of Appeals the denial of the motion to remand. In July 2015 the Fifth Circuit issued an order denying the appeal, and the Attorney General subsequently filed a petition for rehearing of the request for interlocutory appeal, which was also denied. In December 2015 the District Court ordered that the parties submit to the court undisputed and disputed facts that are material to the Entergy defendants’ motion for judgment on the pleadings, as well as supplemental briefs regarding the same. Those filings were made in January 2016. In September 2016 the Attorney General filed a mandamus petition with the U.S. Fifth Circuit Court of Appeals in which the Attorney General asked the Fifth Circuit to order the chief judge to reassign this case to another judge. The District Court denied the Entergy companies’ motion for judgment on the pleadings. The Entergy companies filed a motion seeking to amend the District Court’s order denying the Entergy companies’ motion for judgment on the pleadings and allowing an interlocutory appeal. The Fifth Circuit granted the Attorney General’s motion for writ of mandamus and directed the chief judge to assign the case to a new judge. The case has now been reassigned, and the Entergy companies’ motion to amend the order remains pending. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in the open 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 $10.9 million in 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. Both appeals are pending, but the appeals do not stay the PUCT’s decision. The federal appeal is scheduled to be heard in December 2016. In April 2016, Entergy Texas filed with the PUCT an application to refund to customers approximately $56.2 million . The refund resulted from (i) $41.8 million of fuel cost recovery over-collections through February 2016, (ii) the $10.9 million in bandwidth remedy payments, discussed above, that Entergy Texas received related to calendar year 2006 production costs, and (iii) $3.5 million in bandwidth remedy payments that Entergy Texas received related to 2006-2008 production costs. In June 2016, Entergy Texas filed an unopposed settlement agreement that added additional over-recovered fuel costs for the months of March and April 2016. The settlement resulted in a $68 million refund. The ALJ approved the refund on an interim basis to be made to most customers over a four-month period beginning with the first billing cycle of July 2016. In July 2016 the PUCT issued an order approving the interim refund. In July 2016, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period April 1, 2013 through March 31, 2016. Under a recent PUCT rule change, a fuel reconciliation is required to be filed at least once every three years and outside of a base rate case filing. During the reconciliation period, Entergy Texas incurred approximately $1.77 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimates an over-recovery balance of approximately $19.3 million , including interest, which Entergy Texas is requesting authority to carry over as the beginning balance for the subsequent reconciliation period beginning Apri1 2016. Entergy Texas also notes, however, that the $19.3 million over collection is currently being refunded to customers as a portion of the interim fuel refund beginning with the first billing cycle of July 2016, discussed above. Entergy Texas also is requesting a prudence finding for each of the fuel-related contracts and arrangements entered into or modified during the reconciliation period that have not been reviewed by the PUCT in a prior proceeding. The PUCT has one year to issue a final order in this proceeding. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC 2015 Rate Case In April 2015, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. The filing notified the APSC of Entergy Arkansas’s intent to implement a formula rate review mechanism pursuant to Arkansas legislation passed in 2015, and requested a retail rate increase of $268.4 million , with a net increase in revenue of $167 million. The filing requested a 10.2% return on common equity. In September 2015 the APSC staff and intervenors filed direct testimony, with the APSC staff recommending a revenue requirement of $217.9 million and a 9.65% return on common equity. In December 2015, Entergy Arkansas, the APSC staff, and certain of the intervenors in the rate case filed with the APSC a joint motion for approval of a settlement of the case that proposed a retail rate increase of approximately $225 million with a net increase in revenue of approximately $133 million ; an authorized return on common equity of 9.75% ; and a formula rate plan tariff that provides a +/- 50 basis point band around the 9.75% allowed return on common equity. A significant portion of the rate increase is related to Entergy Arkansas’s acquisition in March 2016 of Union Power Station Power Block 2 for a base purchase price of $237 million , subject to closing adjustments. The settlement agreement also provided for amortization over a 10-year period of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance. A settlement hearing was held in January 2016. In February 2016 the APSC approved the settlement with one exception that would reduce the retail rate increase proposed in the settlement by $5 million . The settling parties agreed to the APSC modifications in February 2016. The new rates were effective February 24, 2016 and began billing with the first billing cycle of April 2016. In March 2016, Entergy Arkansas made a compliance filing regarding the new rates that included an interim base rate adjustment surcharge, effective with the first billing cycle of April 2016, to recover the incremental revenue requirement for the period February 24, 2016 through March 31, 2016. The interim base rate adjustment surcharge will recover a total of $21.1 million over the nine-month period from April 2016 through December 2016. 2016 Formula Rate Plan Filing In July 2016, Entergy Arkansas filed with the APSC its 2016 formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2017 test period to be below the formula rate plan bandwidth. The filing requested a $67.7 million revenue requirement increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . In October 2016, Entergy Arkansas filed with the APSC revised formula rate plan attachments with an updated request for a $54.4 million revenue requirement increase based on acceptance of certain adjustments and recommendations made by the APSC staff and other intervenors, as well as three additional adjustments identified as appropriate by Entergy Arkansas. Also in October 2016, Entergy Arkansas and all parties filed a joint motion to approve a settlement agreement and waive the hearing scheduled for November 2016. The APSC denied the request to waive the hearing, directed certain witnesses to appear, and stated that approval of the settlement agreement would be addressed by a subsequent order. In November 2016 a hearing was held and the APSC issued an order directing the parties to brief certain issues. The parties to the settlement agreement, who reached agreement on all issues and certain additional provisions related to future filing information, requested an order approving the settlement agreement and the proposed $54.4 million revenue requirement increase and rate adjustment by December 9, 2016. If a final order is not issued by this date, the proposed formula rate plan rate adjustment will become effective December 30, 2016, subject to refund. Advanced Metering Infrastructure (AMI) Filing In September 2016, Entergy Arkansas filed an application seeking an order from the APSC finding that Entergy Arkansas’s deployment of AMI is in the public interest. Entergy Arkansas proposed to replace existing meters with advanced meters that enable two-way data communication; design and build a secure and reliable network to support such communications; and implement support systems. AMI is intended to serve as the foundation of Entergy Arkansas’s modernized power grid. The filing identified a number quantified and unquantified benefits, and Entergy Arkansas provided a cost benefit analysis showing that its AMI deployment is expected to produce a nominal net benefit to customers of $431 million . Entergy Arkansas also sought to continue to include in rate base the remaining book value, approximately $57 million , of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Entergy Arkansas proposed a 15-year depreciable life for the new advanced meters, the three-year deployment of which is expected to begin in 2019. Subject to approval by the APSC, deployment of the communications network is expected to begin in 2018. Entergy Arkansas proposed to include the AMI deployment costs and the quantified benefits in future formula rate plan filings. In order to have certainty around its 2018 projected AMI deployment costs, Entergy Arkansas sought an order from the APSC prior to the hearing on its expected 2017 formula rate plan filing in fourth quarter 2017. Filings with the LPSC Retail Rates - Electric 2015 Formula Rate Plan Filing In May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. The evaluation report reflects an earned return on common equity of 9.07% . As such, no adjustment to base formula rate plan revenue is required. The following other adjustments, however, are required under the formula rate plan: an increase in the legacy Entergy Louisiana additional capacity mechanism of $14.2 million ; a separate increase in legacy Entergy Louisiana revenue of $10 million primarily to reflect the effects of the termination of the System Agreement; an increase in the legacy Entergy Gulf States Louisiana additional capacity mechanism of $0.5 million ; a decrease in legacy Entergy Gulf States Louisiana revenue of $58.7 million primarily to reflect the effects of the termination of the System Agreement; and an increase of $11 million to the MISO cost recovery mechanism. Rates were implemented with the first billing cycle of September 2016, subject to refund. Waterford 3 Replacement Steam Generator Project Following the completion of the Waterford 3 replacement steam generator project, the LPSC undertook a prudence review in connection with a filing made by Entergy Louisiana in April 2013 with regard to the following aspects of the replacement project: 1) project management; 2) cost controls; 3) success in achieving stated objectives; 4) the costs of the replacement project; and 5) the outage length and replacement power costs. In July 2014 the LPSC Staff filed testimony recommending potential project and replacement power cost disallowances of up to $71 million , citing a need for further explanation or documentation from Entergy Louisiana. An intervenor filed testimony recommending disallowance of $141 million of incremental project costs, claiming the steam generator fabricator was imprudent. Entergy Louisiana provided further documentation and explanation requested by the LPSC staff. An evidentiary hearing was held in December 2014. At the hearing the parties maintained the positions reflected in pre-filed testimony. Entergy Louisiana believes that the replacement steam generator costs were prudently incurred and applicable legal principles support their recovery in rates. Nevertheless, Entergy Louisiana recorded a write-off of $16 million of Waterford 3’s plant balance in December 2014 because of the uncertainty at the time associated with the resolution of the prudence review. In December 2015 the ALJ issued a proposed recommendation, which was subsequently finalized, concluding that Entergy Louisiana prudently managed the Waterford 3 replacement steam generator project, including the selection, use, and oversight of contractors, and could not reasonably have anticipated the damage to the steam generators. Nevertheless, the ALJ concluded that Entergy Louisiana was liable for the conduct of its contractor and subcontractor and, therefore, recommended a disallowance of $67 million in capital costs. Additionally, the ALJ concluded that Entergy Louisiana did not sufficiently justify the incurrence of $2 million in replacement power costs during the replacement outage. After considering the progress of the proceeding in light of the ALJ recommendation, Entergy Louisiana recorded in the fourth quarter 2015 approximately $77 million in charges, including a $45 million asset write-off and a $32 million regulatory charge, to reflect that a portion of the assets associated with the Waterford 3 replacement steam generator project is no longer probable of recovery. Entergy Louisiana maintains that the ALJ’s recommendation contains significant factual and legal errors. In October 2016 the parties reached a settlement in this matter. If approved by the LPSC, the settlement effectively would provide for an agreed-upon disallowance of $67 million of plant, which had been previously written off by Entergy Louisiana, as discussed above. The settlement would also require a refund to customers of approximately $43 million , representing the revenues previously collected associated with the disallowed plant, including interest, and $2 million of replacement power costs. Entergy Louisiana had previously recorded provisions for these refunds. Additionally, under the settlement, Entergy Louisiana would provide a one-time credit to customers of approximately $24 million , representing the value of potential future service credits agreed to by the project contractor. The settlement provides that Entergy Louisiana can retain the value associated with these service credits, to the extent they are realized in the future. If the settlement is approved by the LPSC, the refunds and one-time credit to customers would be made in December 2016. Ninemile 6 As discussed in the Form 10-K, in July 2015, Entergy Louisiana submitted to the LPSC a Ninemile 6 compliance filing including an estimate at completion, inclusive of interconnection costs and transmission upgrades, of approximately $648 million , or $76 million less than originally estimated, along with other project details and supporting evidence, to enable the LPSC to review the prudence of Entergy Louisiana’s management of the project. Testimony filed by the LPSC staff generally supports the prudence of the management of the project and recovery of the costs incurred to complete the project. The LPSC staff had questioned the warranty coverage for one element of the project. In March 2016, Entergy Louisiana and the LPSC staff filed a joint motion to suspend the procedural schedule pending the filing of an uncontested joint stipulated settlement. In October 2016 all parties agreed to a stipulation providing that 100% of Ninemile 6 construction costs was prudently incurred and is eligible for recovery from customers, but reserving the LPSC’s rights to review the prudence of Entergy Louisiana’s actions regarding one element of the project. This stipulation is subject to LPSC approval. Union Power Station As discussed in the Form 10-K, in October 2015 the LPSC approved a settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station. In March 2016, Entergy Louisiana acquired Power Blocks 3 and 4 of Union Power Station for an aggregate purchase price of approximately $474 million and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. 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. Parties have requested further proceedings on the prudence of Entergy Louisiana’s decision to deactivate Willow Glen 2 and 4. This matter is pending before an ALJ, and a hearing has been scheduled in March 2017 to determine, under applicable law, whether Willow Glen 2 and 4 units should be returned to service. Retail Rates - Gas In January 2016, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2015. The filing showed an earned return on common equity of 10.22% , which is within the authorized bandwidth, therefore requiring no change in rates. In March 2016 the LPSC staff issued its report stating that the 2015 gas rate stabilization plan filing is in compliance with the exception of several issues that require additional information, explanation, or clarification for which the LPSC staff has reserved the right to further review. In July 2016 the parties to the proceeding filed an unopposed joint report and motion for entry of order accepting report that indicates no outstanding issues remain in the filing. Absent approval of an extension by the LPSC, test year 2015 is the final year under the current gas rate stabilization plan. In February 2016, however, Entergy Louisiana filed a motion requesting to extend the term of the gas rate stabilization plan for an additional three-year term. A procedural schedule has been established, including a hearing in November 2016. The LPSC staff filed testimony supportive of the renewal of the gas rate stabilization plan. The parties submitted a motion indicating that they are working toward development of a settlement that they would seek to have approved at the November 2016 hearing. Filings with the MPSC In March 2016, Entergy Mississippi submitted its formula rate plan 2016 test year filing showing Entergy Mississippi’s projected earned return for the 2016 calendar year to be below the formula rate plan bandwidth. The filing showed a $32.6 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 9.96% , within the formula rate plan bandwidth. In June 2016 the MPSC approved Entergy Mississippi’s joint stipulation with the Mississippi Public Utilities Staff. The joint stipulation provided for a total revenue increase of $23.7 million . The revenue increase includes a $19.4 million increase through the formula rate plan, resulting in a return on common equity point of adjustment of 10.07% . The revenue increase also includes $4.3 million in incremental ad valorem tax expenses to be collected through an updated ad valorem tax adjustment rider. The revenue increase and ad valorem tax adjustment rider were effective with the July 2016 bills. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the terms of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6, the revenue requirement associated with the purchase of Power Block 1 of the Union Power Station, and a credit to customers of $400 thousand monthly beginning June 2016 in recognition of the decrease in other operation and maintenance expenses that would result with the deactivation of Michoud Units 2 and 3. In March 2016, Entergy New Orleans purchased Power Block 1 of the Union Power Station for approximately $237 million and initiated recovery of these costs with March 2016 bills. In July 2016, Entergy New Orleans and the City Council Utility Committee agreed to a temporary increase in the Michoud credit to customers to a total of $1.4 million monthly for August 2016 through December 2016. Internal Restructuring In July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring which would result in the transfer of substantially all of the assets and operations of Entergy New Orleans to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval of the City Council and the FERC. The application provided that if it is approved by the City Council in 2016, Entergy New Orleans would credit retail customers $5 million in each of the years 2016 and 2017. Intervenors filed direct testimony and comments in September 2016 and the City Council advisors filed direct testimony in October 2016. A hearing at the City Council scheduled for October 2016 has been continued until December 2016. In October 2016, Entergy New Orleans filed its rebuttal testimony and therein agreed that, given the extended procedural schedule, the $5 million in proposed 2016 credits would still be paid, although on a different schedule, if the City Council approved the restructuring after 2016 but before the end of the first quarter of 2017. The filing with the FERC has not yet been made, but if the restructuring is approved by the FERC by December 31, 2018, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2018, 2019, and 2020. If City Council and FERC approvals are obtained, Entergy New Orleans expects the restructuring will be consummated by December 31, 2017. It is currently contemplated that Entergy New Orleans would undertake a multi-step restructuring, which would include the following: • Entergy New Orleans would redeem its outstanding preferred stock at a price of approximately $21 million , which includes an expected call premium of approximately $819,000 , plus any accumulated and unpaid dividends. • Entergy New Orleans would convert from a Louisiana corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy New Orleans will allocate substantially all of its assets to a new subsidiary, Entergy New Orleans Power, LLC, a Texas limited liability company (Entergy New Orleans Power), and Entergy New Orleans Power will assume substantially all of the liabilities of Entergy New Orleans, in a transaction regarded as a merger under the TXBOC. Entergy New Orleans will remain in existence and hold the membership interests in Entergy New Orleans Power. • Entergy New Orleans will contribute the membership interests in Entergy New Orleans Power to an affiliate (Entergy Utility Holding Company, LLC
System Energy [Member]
Public Utilities Disclosure [Text Block]	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2016, Entergy Arkansas filed its annual rate redetermination pursuant to the production cost allocation rider, which reflected recovery of the production cost allocation rider true-up adjustment of the 2014 and 2015 unrecovered retail balance in the amount of $1.9 million . Additionally, the redetermined rates reflected the recovery of a $1.9 million System Agreement bandwidth remedy payment resulting from a compliance filing pursuant to the FERC’s December 2015 order related to test year 2009 production costs. The rates for the 2016 production cost allocation rider update became effective with the first billing cycle of July 2016, and rates will be effective through June 2017. Entergy Louisiana In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. The LPSC staff issued its audit report in January 2013. The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million , plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates. The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing. Two parties intervened in the proceeding. A procedural schedule was established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC staff report and any issues raised by intervenors. One intervenor sought further proceedings regarding certain issues it raised in its comments on the LPSC staff report. Entergy Louisiana filed responses to both the LPSC staff report and the issues raised by the intervenor. After conducting additional discovery, in April 2016 the LPSC staff consultant issued its supplemental audit report, which concluded that Entergy Louisiana was not imprudent on the issues raised by the intervenor. The intervenor has stated that it does not intend to pursue these issues further. In October 2016 the LPSC staff filed testimony affirming the recommendation in its audit report that nuclear dry fuel storage costs should be realigned to base rates. A procedural schedule has been established for this proceeding, including an evidentiary hearing in November 2016. In December 2011 the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through 2009. In March 2016 the LPSC staff consultant issued its audit report. In its report, the LPSC staff consultant recommended that Entergy Louisiana refund approximately $8.6 million , plus interest, to customers and realign the recovery of approximately $12.7 million from Entergy Gulf States Louisiana’s fuel adjustment clause to base rates. In September 2016 the LPSC staff filed testimony stating that is was no longer recommending a disallowance of $3.4 million of the $8.6 million discussed above, but otherwise maintained positions from its report. Entergy Louisiana has recorded a provision for the estimated outcome of this proceeding. A procedural schedule has been established for this proceeding, including a hearing in December 2016. In June 2016 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. In recognition of the business combination that occurred in 2015, the audit notice was issued to Entergy Louisiana and will also include a review of charges to legacy Entergy Gulf States Louisiana customers prior to the business combination. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment and purchased gas adjustment mechanisms for the period from 2012 through 2015. Discovery has not commenced. Entergy Mississippi Entergy Mississippi had a deferred fuel over-recovery balance of $58.3 million as of May 31, 2015, along with an under-recovery balance of $12.3 million under the power management rider. Pursuant to those tariffs, in July 2015, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider to flow through to customers the approximately $46 million net over-recovery over a six-month period. In August 2015 the MPSC approved the interim adjustments effective with September 2015 bills. In November 2015, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included a projected over-recovery balance of $48 million projected through January 31, 2016. In January 2016 the MPSC approved the redetermined annual factor effective February 1, 2016. The MPSC further ordered, however, that due to the significant change in natural gas price forecasts since Entergy Mississippi’s filing in November 2015, Entergy Mississippi shall file a revised fuel factor with the MPSC no later than February 1, 2016. Pursuant to that order, Entergy Mississippi submitted a revised fuel factor. Additionally, because Entergy Mississippi’s projected over-recovery balance for the period ending January 31, 2017 was $68 million , in February 2016, Entergy Mississippi filed for another interim adjustment to the energy cost factor effective April 2016 to flow through to customers the projected over-recovery balance over a six-month period. That interim adjustment was approved by the MPSC in February 2016 effective for April 2016 bills. Mississippi Attorney General Complaint 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 complaint is wide ranging and relates to tariffs and procedures under which Entergy Mississippi purchases power not generated in Mississippi to meet electricity demand. Entergy believes the complaint is unfounded. In December 2008 the defendant Entergy companies removed the Attorney General’s lawsuit to U.S. District Court in Jackson, Mississippi. The Mississippi attorney general moved to remand the matter to state court. In August 2012 the District Court issued an opinion denying the Attorney General’s motion for remand, finding that the District Court has subject matter jurisdiction under the Class Action Fairness Act. The defendant Entergy companies answered the complaint and filed a counterclaim for relief based upon the Mississippi Public Utilities Act and the Federal Power Act. In May 2009 the defendant Entergy companies filed a motion for judgment on the pleadings asserting grounds of federal preemption, the exclusive jurisdiction of the MPSC, and factual errors in the Attorney General’s complaint. In September 2012 the District Court heard oral argument on Entergy’s motion for judgment on the pleadings. In January 2014 the U.S. Supreme Court issued a decision in which it held that cases brought by attorneys general as the sole plaintiff to enforce state laws were not considered “mass actions” under the Class Action Fairness Act, so as to establish federal subject matter jurisdiction. One day later the Attorney General renewed his motion to remand the Entergy case back to state court, citing the U.S. Supreme Court’s decision. The defendant Entergy companies responded to that motion reiterating the additional grounds asserted for federal question jurisdiction, and the District Court held oral argument on the renewed motion to remand in February 2014. In April 2015 the District Court entered an order denying the renewed motion to remand, holding that the District Court has federal question subject matter jurisdiction. The Attorney General appealed to the U.S. Fifth Circuit Court of Appeals the denial of the motion to remand. In July 2015 the Fifth Circuit issued an order denying the appeal, and the Attorney General subsequently filed a petition for rehearing of the request for interlocutory appeal, which was also denied. In December 2015 the District Court ordered that the parties submit to the court undisputed and disputed facts that are material to the Entergy defendants’ motion for judgment on the pleadings, as well as supplemental briefs regarding the same. Those filings were made in January 2016. In September 2016 the Attorney General filed a mandamus petition with the U.S. Fifth Circuit Court of Appeals in which the Attorney General asked the Fifth Circuit to order the chief judge to reassign this case to another judge. The District Court denied the Entergy companies’ motion for judgment on the pleadings. The Entergy companies filed a motion seeking to amend the District Court’s order denying the Entergy companies’ motion for judgment on the pleadings and allowing an interlocutory appeal. The Fifth Circuit granted the Attorney General’s motion for writ of mandamus and directed the chief judge to assign the case to a new judge. The case has now been reassigned, and the Entergy companies’ motion to amend the order remains pending. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in the open 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 $10.9 million in 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. Both appeals are pending, but the appeals do not stay the PUCT’s decision. The federal appeal is scheduled to be heard in December 2016. In April 2016, Entergy Texas filed with the PUCT an application to refund to customers approximately $56.2 million . The refund resulted from (i) $41.8 million of fuel cost recovery over-collections through February 2016, (ii) the $10.9 million in bandwidth remedy payments, discussed above, that Entergy Texas received related to calendar year 2006 production costs, and (iii) $3.5 million in bandwidth remedy payments that Entergy Texas received related to 2006-2008 production costs. In June 2016, Entergy Texas filed an unopposed settlement agreement that added additional over-recovered fuel costs for the months of March and April 2016. The settlement resulted in a $68 million refund. The ALJ approved the refund on an interim basis to be made to most customers over a four-month period beginning with the first billing cycle of July 2016. In July 2016 the PUCT issued an order approving the interim refund. In July 2016, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period April 1, 2013 through March 31, 2016. Under a recent PUCT rule change, a fuel reconciliation is required to be filed at least once every three years and outside of a base rate case filing. During the reconciliation period, Entergy Texas incurred approximately $1.77 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimates an over-recovery balance of approximately $19.3 million , including interest, which Entergy Texas is requesting authority to carry over as the beginning balance for the subsequent reconciliation period beginning Apri1 2016. Entergy Texas also notes, however, that the $19.3 million over collection is currently being refunded to customers as a portion of the interim fuel refund beginning with the first billing cycle of July 2016, discussed above. Entergy Texas also is requesting a prudence finding for each of the fuel-related contracts and arrangements entered into or modified during the reconciliation period that have not been reviewed by the PUCT in a prior proceeding. The PUCT has one year to issue a final order in this proceeding. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC 2015 Rate Case In April 2015, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. The filing notified the APSC of Entergy Arkansas’s intent to implement a formula rate review mechanism pursuant to Arkansas legislation passed in 2015, and requested a retail rate increase of $268.4 million , with a net increase in revenue of $167 million. The filing requested a 10.2% return on common equity. In September 2015 the APSC staff and intervenors filed direct testimony, with the APSC staff recommending a revenue requirement of $217.9 million and a 9.65% return on common equity. In December 2015, Entergy Arkansas, the APSC staff, and certain of the intervenors in the rate case filed with the APSC a joint motion for approval of a settlement of the case that proposed a retail rate increase of approximately $225 million with a net increase in revenue of approximately $133 million ; an authorized return on common equity of 9.75% ; and a formula rate plan tariff that provides a +/- 50 basis point band around the 9.75% allowed return on common equity. A significant portion of the rate increase is related to Entergy Arkansas’s acquisition in March 2016 of Union Power Station Power Block 2 for a base purchase price of $237 million , subject to closing adjustments. The settlement agreement also provided for amortization over a 10-year period of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance. A settlement hearing was held in January 2016. In February 2016 the APSC approved the settlement with one exception that would reduce the retail rate increase proposed in the settlement by $5 million . The settling parties agreed to the APSC modifications in February 2016. The new rates were effective February 24, 2016 and began billing with the first billing cycle of April 2016. In March 2016, Entergy Arkansas made a compliance filing regarding the new rates that included an interim base rate adjustment surcharge, effective with the first billing cycle of April 2016, to recover the incremental revenue requirement for the period February 24, 2016 through March 31, 2016. The interim base rate adjustment surcharge will recover a total of $21.1 million over the nine-month period from April 2016 through December 2016. 2016 Formula Rate Plan Filing In July 2016, Entergy Arkansas filed with the APSC its 2016 formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2017 test period to be below the formula rate plan bandwidth. The filing requested a $67.7 million revenue requirement increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . In October 2016, Entergy Arkansas filed with the APSC revised formula rate plan attachments with an updated request for a $54.4 million revenue requirement increase based on acceptance of certain adjustments and recommendations made by the APSC staff and other intervenors, as well as three additional adjustments identified as appropriate by Entergy Arkansas. Also in October 2016, Entergy Arkansas and all parties filed a joint motion to approve a settlement agreement and waive the hearing scheduled for November 2016. The APSC denied the request to waive the hearing, directed certain witnesses to appear, and stated that approval of the settlement agreement would be addressed by a subsequent order. In November 2016 a hearing was held and the APSC issued an order directing the parties to brief certain issues. The parties to the settlement agreement, who reached agreement on all issues and certain additional provisions related to future filing information, requested an order approving the settlement agreement and the proposed $54.4 million revenue requirement increase and rate adjustment by December 9, 2016. If a final order is not issued by this date, the proposed formula rate plan rate adjustment will become effective December 30, 2016, subject to refund. Advanced Metering Infrastructure (AMI) Filing In September 2016, Entergy Arkansas filed an application seeking an order from the APSC finding that Entergy Arkansas’s deployment of AMI is in the public interest. Entergy Arkansas proposed to replace existing meters with advanced meters that enable two-way data communication; design and build a secure and reliable network to support such communications; and implement support systems. AMI is intended to serve as the foundation of Entergy Arkansas’s modernized power grid. The filing identified a number quantified and unquantified benefits, and Entergy Arkansas provided a cost benefit analysis showing that its AMI deployment is expected to produce a nominal net benefit to customers of $431 million . Entergy Arkansas also sought to continue to include in rate base the remaining book value, approximately $57 million , of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Entergy Arkansas proposed a 15-year depreciable life for the new advanced meters, the three-year deployment of which is expected to begin in 2019. Subject to approval by the APSC, deployment of the communications network is expected to begin in 2018. Entergy Arkansas proposed to include the AMI deployment costs and the quantified benefits in future formula rate plan filings. In order to have certainty around its 2018 projected AMI deployment costs, Entergy Arkansas sought an order from the APSC prior to the hearing on its expected 2017 formula rate plan filing in fourth quarter 2017. Filings with the LPSC Retail Rates - Electric 2015 Formula Rate Plan Filing In May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. The evaluation report reflects an earned return on common equity of 9.07% . As such, no adjustment to base formula rate plan revenue is required. The following other adjustments, however, are required under the formula rate plan: an increase in the legacy Entergy Louisiana additional capacity mechanism of $14.2 million ; a separate increase in legacy Entergy Louisiana revenue of $10 million primarily to reflect the effects of the termination of the System Agreement; an increase in the legacy Entergy Gulf States Louisiana additional capacity mechanism of $0.5 million ; a decrease in legacy Entergy Gulf States Louisiana revenue of $58.7 million primarily to reflect the effects of the termination of the System Agreement; and an increase of $11 million to the MISO cost recovery mechanism. Rates were implemented with the first billing cycle of September 2016, subject to refund. Waterford 3 Replacement Steam Generator Project Following the completion of the Waterford 3 replacement steam generator project, the LPSC undertook a prudence review in connection with a filing made by Entergy Louisiana in April 2013 with regard to the following aspects of the replacement project: 1) project management; 2) cost controls; 3) success in achieving stated objectives; 4) the costs of the replacement project; and 5) the outage length and replacement power costs. In July 2014 the LPSC Staff filed testimony recommending potential project and replacement power cost disallowances of up to $71 million , citing a need for further explanation or documentation from Entergy Louisiana. An intervenor filed testimony recommending disallowance of $141 million of incremental project costs, claiming the steam generator fabricator was imprudent. Entergy Louisiana provided further documentation and explanation requested by the LPSC staff. An evidentiary hearing was held in December 2014. At the hearing the parties maintained the positions reflected in pre-filed testimony. Entergy Louisiana believes that the replacement steam generator costs were prudently incurred and applicable legal principles support their recovery in rates. Nevertheless, Entergy Louisiana recorded a write-off of $16 million of Waterford 3’s plant balance in December 2014 because of the uncertainty at the time associated with the resolution of the prudence review. In December 2015 the ALJ issued a proposed recommendation, which was subsequently finalized, concluding that Entergy Louisiana prudently managed the Waterford 3 replacement steam generator project, including the selection, use, and oversight of contractors, and could not reasonably have anticipated the damage to the steam generators. Nevertheless, the ALJ concluded that Entergy Louisiana was liable for the conduct of its contractor and subcontractor and, therefore, recommended a disallowance of $67 million in capital costs. Additionally, the ALJ concluded that Entergy Louisiana did not sufficiently justify the incurrence of $2 million in replacement power costs during the replacement outage. After considering the progress of the proceeding in light of the ALJ recommendation, Entergy Louisiana recorded in the fourth quarter 2015 approximately $77 million in charges, including a $45 million asset write-off and a $32 million regulatory charge, to reflect that a portion of the assets associated with the Waterford 3 replacement steam generator project is no longer probable of recovery. Entergy Louisiana maintains that the ALJ’s recommendation contains significant factual and legal errors. In October 2016 the parties reached a settlement in this matter. If approved by the LPSC, the settlement effectively would provide for an agreed-upon disallowance of $67 million of plant, which had been previously written off by Entergy Louisiana, as discussed above. The settlement would also require a refund to customers of approximately $43 million , representing the revenues previously collected associated with the disallowed plant, including interest, and $2 million of replacement power costs. Entergy Louisiana had previously recorded provisions for these refunds. Additionally, under the settlement, Entergy Louisiana would provide a one-time credit to customers of approximately $24 million , representing the value of potential future service credits agreed to by the project contractor. The settlement provides that Entergy Louisiana can retain the value associated with these service credits, to the extent they are realized in the future. If the settlement is approved by the LPSC, the refunds and one-time credit to customers would be made in December 2016. Ninemile 6 As discussed in the Form 10-K, in July 2015, Entergy Louisiana submitted to the LPSC a Ninemile 6 compliance filing including an estimate at completion, inclusive of interconnection costs and transmission upgrades, of approximately $648 million , or $76 million less than originally estimated, along with other project details and supporting evidence, to enable the LPSC to review the prudence of Entergy Louisiana’s management of the project. Testimony filed by the LPSC staff generally supports the prudence of the management of the project and recovery of the costs incurred to complete the project. The LPSC staff had questioned the warranty coverage for one element of the project. In March 2016, Entergy Louisiana and the LPSC staff filed a joint motion to suspend the procedural schedule pending the filing of an uncontested joint stipulated settlement. In October 2016 all parties agreed to a stipulation providing that 100% of Ninemile 6 construction costs was prudently incurred and is eligible for recovery from customers, but reserving the LPSC’s rights to review the prudence of Entergy Louisiana’s actions regarding one element of the project. This stipulation is subject to LPSC approval. Union Power Station As discussed in the Form 10-K, in October 2015 the LPSC approved a settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station. In March 2016, Entergy Louisiana acquired Power Blocks 3 and 4 of Union Power Station for an aggregate purchase price of approximately $474 million and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. 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. Parties have requested further proceedings on the prudence of Entergy Louisiana’s decision to deactivate Willow Glen 2 and 4. This matter is pending before an ALJ, and a hearing has been scheduled in March 2017 to determine, under applicable law, whether Willow Glen 2 and 4 units should be returned to service. Retail Rates - Gas In January 2016, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2015. The filing showed an earned return on common equity of 10.22% , which is within the authorized bandwidth, therefore requiring no change in rates. In March 2016 the LPSC staff issued its report stating that the 2015 gas rate stabilization plan filing is in compliance with the exception of several issues that require additional information, explanation, or clarification for which the LPSC staff has reserved the right to further review. In July 2016 the parties to the proceeding filed an unopposed joint report and motion for entry of order accepting report that indicates no outstanding issues remain in the filing. Absent approval of an extension by the LPSC, test year 2015 is the final year under the current gas rate stabilization plan. In February 2016, however, Entergy Louisiana filed a motion requesting to extend the term of the gas rate stabilization plan for an additional three-year term. A procedural schedule has been established, including a hearing in November 2016. The LPSC staff filed testimony supportive of the renewal of the gas rate stabilization plan. The parties submitted a motion indicating that they are working toward development of a settlement that they would seek to have approved at the November 2016 hearing. Filings with the MPSC In March 2016, Entergy Mississippi submitted its formula rate plan 2016 test year filing showing Entergy Mississippi’s projected earned return for the 2016 calendar year to be below the formula rate plan bandwidth. The filing showed a $32.6 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 9.96% , within the formula rate plan bandwidth. In June 2016 the MPSC approved Entergy Mississippi’s joint stipulation with the Mississippi Public Utilities Staff. The joint stipulation provided for a total revenue increase of $23.7 million . The revenue increase includes a $19.4 million increase through the formula rate plan, resulting in a return on common equity point of adjustment of 10.07% . The revenue increase also includes $4.3 million in incremental ad valorem tax expenses to be collected through an updated ad valorem tax adjustment rider. The revenue increase and ad valorem tax adjustment rider were effective with the July 2016 bills. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the terms of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6, the revenue requirement associated with the purchase of Power Block 1 of the Union Power Station, and a credit to customers of $400 thousand monthly beginning June 2016 in recognition of the decrease in other operation and maintenance expenses that would result with the deactivation of Michoud Units 2 and 3. In March 2016, Entergy New Orleans purchased Power Block 1 of the Union Power Station for approximately $237 million and initiated recovery of these costs with March 2016 bills. In July 2016, Entergy New Orleans and the City Council Utility Committee agreed to a temporary increase in the Michoud credit to customers to a total of $1.4 million monthly for August 2016 through December 2016. Internal Restructuring In July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring which would result in the transfer of substantially all of the assets and operations of Entergy New Orleans to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval of the City Council and the FERC. The application provided that if it is approved by the City Council in 2016, Entergy New Orleans would credit retail customers $5 million in each of the years 2016 and 2017. Intervenors filed direct testimony and comments in September 2016 and the City Council advisors filed direct testimony in October 2016. A hearing at the City Council scheduled for October 2016 has been continued until December 2016. In October 2016, Entergy New Orleans filed its rebuttal testimony and therein agreed that, given the extended procedural schedule, the $5 million in proposed 2016 credits would still be paid, although on a different schedule, if the City Council approved the restructuring after 2016 but before the end of the first quarter of 2017. The filing with the FERC has not yet been made, but if the restructuring is approved by the FERC by December 31, 2018, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2018, 2019, and 2020. If City Council and FERC approvals are obtained, Entergy New Orleans expects the restructuring will be consummated by December 31, 2017. It is currently contemplated that Entergy New Orleans would undertake a multi-step restructuring, which would include the following: • Entergy New Orleans would redeem its outstanding preferred stock at a price of approximately $21 million , which includes an expected call premium of approximately $819,000 , plus any accumulated and unpaid dividends. • Entergy New Orleans would convert from a Louisiana corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy New Orleans will allocate substantially all of its assets to a new subsidiary, Entergy New Orleans Power, LLC, a Texas limited liability company (Entergy New Orleans Power), and Entergy New Orleans Power will assume substantially all of the liabilities of Entergy New Orleans, in a transaction regarded as a merger under the TXBOC. Entergy New Orleans will remain in existence and hold the membership interests in Entergy New Orleans Power. • Entergy New Orleans will contribute the membership interests in Entergy New Orleans Power to an affiliate (Entergy Utility Holding Company, LLC

Equity

Equity	9 Months Ended
	Sep. 30, 2016
Equity	EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and System Energy) Common Stock Earnings (loss) per Share The following table presents Entergy’s basic and diluted earnings (loss) per share calculations included on the consolidated statements of operations: For the Three Months Ended September 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings (loss) per share Income Shares $/share Loss Shares $/share Net income (loss) attributable to Entergy Corporation $388.2 179.0 $2.17 ($723.0 ) 179.2 ($4.04 ) Average dilutive effect of: Stock options 0.3 — — — Other equity plans 0.7 (0.01 ) — — Diluted earnings (loss) per share $388.2 180.0 $2.16 ($723.0 ) 179.2 ($4.04 ) The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 3.5 million for the three months ended September 30, 2016 and approximately 7.4 million for the three months ended September 30, 2015 . For the Nine Months Ended September 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings (loss) per share Income Shares $/share Loss Shares $/share Net income (loss) attributable to Entergy Corporation $1,185.4 178.8 $6.63 ($276.1 ) 179.4 ($1.54 ) Average dilutive effect of: Stock options 0.2 (0.01 ) — — Other equity plans 0.5 (0.02 ) — — Diluted earnings (loss) per share $1,185.4 179.5 $6.60 ($276.1 ) 179.4 ($1.54 ) The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 4.6 million for the nine months ended September 30, 2016 and approximately 7.4 million for the nine months ended September 30, 2015 . 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. In May 2016, System Energy paid its parent, Entergy Corporation, a $40 million distribution out of its common stock. Treasury Stock During the nine months ended September 30, 2016 , Entergy Corporation issued 738,579 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, 2016 . Preferred Stock In September 2016, Entergy Arkansas redeemed $10 million of its 6.08% Series preferred stock and $75 million of its 6.45% Series preferred stock. In October 2016, Entergy Mississippi redeemed $30 million of its 6.25% Series preferred stock. Retained Earnings On October 28, 2016, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.87 per share, payable on December 1, 2016, to holders of record as of November 10, 2016. 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, 2016 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, July 1, 2016 $32,423 ($453,999 ) $411,581 $840 ($9,155 ) Other comprehensive income (loss) before reclassifications 45,162 — 23,039 (92 ) 68,109 Amounts reclassified from accumulated other comprehensive income (loss) (24,190 ) 5,044 (1,672 ) — (20,818 ) Net other comprehensive income (loss) for the period 20,972 5,044 21,367 (92 ) 47,291 Ending balance, September 30, 2016 $53,395 ($448,955 ) $432,948 $748 $38,136 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2015 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, July 1, 2015 $107,484 ($553,903 ) $396,818 $2,785 ($46,816 ) Other comprehensive income (loss) before reclassifications 31,620 — (50,760 ) (469 ) (19,609 ) Amounts reclassified from accumulated other comprehensive income (loss) (55,604 ) 7,437 (3,206 ) — (51,373 ) Net other comprehensive income (loss) for the period (23,984 ) 7,437 (53,966 ) (469 ) (70,982 ) Ending balance, September 30, 2015 $83,500 ($546,466 ) $342,852 $2,316 ($117,798 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2016 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, 2016 $105,970 ($466,604 ) $367,557 $2,028 $8,951 Other comprehensive income (loss) before reclassifications 101,071 — 72,087 (1,280 ) 171,878 Amounts reclassified from accumulated other comprehensive income (loss) (153,646 ) 17,649 (6,696 ) — (142,693 ) Net other comprehensive income (loss) for the period (52,575 ) 17,649 65,391 (1,280 ) 29,185 Ending balance, September 30, 2016 $53,395 ($448,955 ) $432,948 $748 $38,136 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2015 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, 2015 $98,118 ($569,789 ) $426,695 $2,669 ($42,307 ) Other comprehensive income (loss) before reclassifications 99,520 13 (63,210 ) (353 ) 35,970 Amounts reclassified from accumulated other comprehensive income (loss) (114,138 ) 23,310 (20,633 ) — (111,461 ) Net other comprehensive income (loss) for the period (14,618 ) 23,323 (83,843 ) (353 ) (75,491 ) Ending balance, September 30, 2015 $83,500 ($546,466 ) $342,852 $2,316 ($117,798 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2016 : Pension and Other (In Thousands) Beginning balance July 1, 2016 ($56,905 ) Amounts reclassified from accumulated other (232 ) Net other comprehensive income (loss) for the period (232 ) Ending balance, September 30, 2016 ($57,137 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2015 : Pension and Other (In Thousands) Beginning balance July 1, 2015 ($78,431 ) Amounts reclassified from accumulated other 412 Net other comprehensive income (loss) for the period 412 Ending balance, September 30, 2015 ($78,019 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2016 : Pension and Other (In Thousands) Beginning balance, January 1, 2016 ($56,412 ) Amounts reclassified from accumulated other (725 ) Net other comprehensive income (loss) for the period (725 ) Ending balance, September 30, 2016 ($57,137 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2015 : Pension and Other (In Thousands) Beginning balance, January 1, 2015 ($79,223 ) Amounts reclassified from accumulated other 1,204 Net other comprehensive income (loss) for the period 1,204 Ending balance, September 30, 2015 ($78,019 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended September 30, 2016 are as follows: Amounts reclassified from AOCI Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $37,550 Competitive business operating revenues Interest rate swaps (334 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 37,216 (13,026 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $24,190 Pension and other postretirement liabilities Amortization of prior-service credit $7,354 (a) Amortization of loss (15,183 ) (a) Settlement loss (1,279 ) (a) Total amortization (9,108 ) 4,064 Income taxes Total amortization (net of tax) ($5,044 ) Net unrealized investment gain (loss) Realized gain (loss) $3,279 Interest and investment income (1,607 ) Income taxes Total realized investment gain (loss) (net of tax) $1,672 Total reclassifications for the period (net of tax) $20,818 (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) for Entergy for the three months ended September 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $86,020 Competitive business operating revenues Interest rate swaps (477 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 85,543 (29,939 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $55,604 Pension and other postretirement liabilities Amortization of prior-service credit $5,985 (a) Amortization of loss (17,588 ) (a) Total amortization (11,603 ) 4,166 Income taxes Total amortization (net of tax) ($7,437 ) Net unrealized investment gain (loss) Realized gain (loss) $6,286 Interest and investment income (3,080 ) Income taxes Total realized investment gain (loss) (net of tax) $3,206 Total reclassifications for the period (net of tax) $51,373 (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) for Entergy for the nine months ended September 30, 2016 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $237,483 Competitive business operating revenues Interest rate swaps (1,104 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 236,379 (82,733 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $153,646 Pension and other postretirement liabilities Amortization of prior-service credit $22,064 (a) Amortization of loss (45,535 ) (a) Settlement loss (1,279 ) (a) Total amortization (24,750 ) 7,101 Income taxes Total amortization (net of tax) ($17,649 ) Net unrealized investment gain (loss) Realized gain (loss) $13,129 Interest and investment income (6,433 ) Income taxes Total realized investment gain (loss) (net of tax) $6,696 Total reclassifications for the period (net of tax) $142,693 (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) for Entergy for the nine months ended September 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $177,129 Competitive business operating revenues Interest rate swaps (1,533 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 175,596 (61,458 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $114,138 Pension and other postretirement liabilities Amortization of prior-service credit $17,956 (a) Amortization of loss (52,764 ) (a) Total amortization (34,808 ) 11,498 Income taxes Total amortization (net of tax) ($23,310 ) Net unrealized investment gain (loss) Realized gain (loss) $40,457 Interest and investment income (19,824 ) Income taxes Total realized investment gain (loss) (net of tax) $20,633 Total reclassifications for the period (net of tax) $111,461 (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) for Entergy Louisiana for the three months ended September 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,947 (a) Amortization of loss (1,570 ) (a) Total amortization 377 (145 ) Income taxes Total amortization (net of tax) 232 Total reclassifications for the period (net of tax) $232 (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) for Entergy Louisiana for the three months ended September 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,866 (a) Amortization of loss (2,536 ) (a) Total amortization (670 ) 258 Income taxes Total amortization (net of tax) (412 ) Total reclassifications for the period (net of tax) ($412 ) (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) for Entergy Louisiana for the nine months ended September 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,841 (a) Amortization of loss (4,712 ) (a) Total amortization 1,129 (404 ) Income taxes Total amortization (net of tax) 725 Total reclassifications for the period (net of tax) $725 (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) for Entergy Louisiana for the nine months ended September 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,599 (a) Amortization of loss (7,606 ) (a) Total amortization (2,007 ) 803 Income taxes Total amortization (net of tax) (1,204 ) Total reclassifications for the period (net of tax) ($1,204 ) (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 Arkansas [Member]
Equity	EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and System Energy) Common Stock Earnings (loss) per Share The following table presents Entergy’s basic and diluted earnings (loss) per share calculations included on the consolidated statements of operations: For the Three Months Ended September 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings (loss) per share Income Shares $/share Loss Shares $/share Net income (loss) attributable to Entergy Corporation $388.2 179.0 $2.17 ($723.0 ) 179.2 ($4.04 ) Average dilutive effect of: Stock options 0.3 — — — Other equity plans 0.7 (0.01 ) — — Diluted earnings (loss) per share $388.2 180.0 $2.16 ($723.0 ) 179.2 ($4.04 ) The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 3.5 million for the three months ended September 30, 2016 and approximately 7.4 million for the three months ended September 30, 2015 . For the Nine Months Ended September 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings (loss) per share Income Shares $/share Loss Shares $/share Net income (loss) attributable to Entergy Corporation $1,185.4 178.8 $6.63 ($276.1 ) 179.4 ($1.54 ) Average dilutive effect of: Stock options 0.2 (0.01 ) — — Other equity plans 0.5 (0.02 ) — — Diluted earnings (loss) per share $1,185.4 179.5 $6.60 ($276.1 ) 179.4 ($1.54 ) The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 4.6 million for the nine months ended September 30, 2016 and approximately 7.4 million for the nine months ended September 30, 2015 . 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. In May 2016, System Energy paid its parent, Entergy Corporation, a $40 million distribution out of its common stock. Treasury Stock During the nine months ended September 30, 2016 , Entergy Corporation issued 738,579 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, 2016 . Preferred Stock In September 2016, Entergy Arkansas redeemed $10 million of its 6.08% Series preferred stock and $75 million of its 6.45% Series preferred stock. In October 2016, Entergy Mississippi redeemed $30 million of its 6.25% Series preferred stock. Retained Earnings On October 28, 2016, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.87 per share, payable on December 1, 2016, to holders of record as of November 10, 2016. 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, 2016 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, July 1, 2016 $32,423 ($453,999 ) $411,581 $840 ($9,155 ) Other comprehensive income (loss) before reclassifications 45,162 — 23,039 (92 ) 68,109 Amounts reclassified from accumulated other comprehensive income (loss) (24,190 ) 5,044 (1,672 ) — (20,818 ) Net other comprehensive income (loss) for the period 20,972 5,044 21,367 (92 ) 47,291 Ending balance, September 30, 2016 $53,395 ($448,955 ) $432,948 $748 $38,136 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2015 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, July 1, 2015 $107,484 ($553,903 ) $396,818 $2,785 ($46,816 ) Other comprehensive income (loss) before reclassifications 31,620 — (50,760 ) (469 ) (19,609 ) Amounts reclassified from accumulated other comprehensive income (loss) (55,604 ) 7,437 (3,206 ) — (51,373 ) Net other comprehensive income (loss) for the period (23,984 ) 7,437 (53,966 ) (469 ) (70,982 ) Ending balance, September 30, 2015 $83,500 ($546,466 ) $342,852 $2,316 ($117,798 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2016 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, 2016 $105,970 ($466,604 ) $367,557 $2,028 $8,951 Other comprehensive income (loss) before reclassifications 101,071 — 72,087 (1,280 ) 171,878 Amounts reclassified from accumulated other comprehensive income (loss) (153,646 ) 17,649 (6,696 ) — (142,693 ) Net other comprehensive income (loss) for the period (52,575 ) 17,649 65,391 (1,280 ) 29,185 Ending balance, September 30, 2016 $53,395 ($448,955 ) $432,948 $748 $38,136 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2015 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, 2015 $98,118 ($569,789 ) $426,695 $2,669 ($42,307 ) Other comprehensive income (loss) before reclassifications 99,520 13 (63,210 ) (353 ) 35,970 Amounts reclassified from accumulated other comprehensive income (loss) (114,138 ) 23,310 (20,633 ) — (111,461 ) Net other comprehensive income (loss) for the period (14,618 ) 23,323 (83,843 ) (353 ) (75,491 ) Ending balance, September 30, 2015 $83,500 ($546,466 ) $342,852 $2,316 ($117,798 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2016 : Pension and Other (In Thousands) Beginning balance July 1, 2016 ($56,905 ) Amounts reclassified from accumulated other (232 ) Net other comprehensive income (loss) for the period (232 ) Ending balance, September 30, 2016 ($57,137 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2015 : Pension and Other (In Thousands) Beginning balance July 1, 2015 ($78,431 ) Amounts reclassified from accumulated other 412 Net other comprehensive income (loss) for the period 412 Ending balance, September 30, 2015 ($78,019 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2016 : Pension and Other (In Thousands) Beginning balance, January 1, 2016 ($56,412 ) Amounts reclassified from accumulated other (725 ) Net other comprehensive income (loss) for the period (725 ) Ending balance, September 30, 2016 ($57,137 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2015 : Pension and Other (In Thousands) Beginning balance, January 1, 2015 ($79,223 ) Amounts reclassified from accumulated other 1,204 Net other comprehensive income (loss) for the period 1,204 Ending balance, September 30, 2015 ($78,019 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended September 30, 2016 are as follows: Amounts reclassified from AOCI Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $37,550 Competitive business operating revenues Interest rate swaps (334 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 37,216 (13,026 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $24,190 Pension and other postretirement liabilities Amortization of prior-service credit $7,354 (a) Amortization of loss (15,183 ) (a) Settlement loss (1,279 ) (a) Total amortization (9,108 ) 4,064 Income taxes Total amortization (net of tax) ($5,044 ) Net unrealized investment gain (loss) Realized gain (loss) $3,279 Interest and investment income (1,607 ) Income taxes Total realized investment gain (loss) (net of tax) $1,672 Total reclassifications for the period (net of tax) $20,818 (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) for Entergy for the three months ended September 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $86,020 Competitive business operating revenues Interest rate swaps (477 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 85,543 (29,939 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $55,604 Pension and other postretirement liabilities Amortization of prior-service credit $5,985 (a) Amortization of loss (17,588 ) (a) Total amortization (11,603 ) 4,166 Income taxes Total amortization (net of tax) ($7,437 ) Net unrealized investment gain (loss) Realized gain (loss) $6,286 Interest and investment income (3,080 ) Income taxes Total realized investment gain (loss) (net of tax) $3,206 Total reclassifications for the period (net of tax) $51,373 (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) for Entergy for the nine months ended September 30, 2016 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $237,483 Competitive business operating revenues Interest rate swaps (1,104 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 236,379 (82,733 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $153,646 Pension and other postretirement liabilities Amortization of prior-service credit $22,064 (a) Amortization of loss (45,535 ) (a) Settlement loss (1,279 ) (a) Total amortization (24,750 ) 7,101 Income taxes Total amortization (net of tax) ($17,649 ) Net unrealized investment gain (loss) Realized gain (loss) $13,129 Interest and investment income (6,433 ) Income taxes Total realized investment gain (loss) (net of tax) $6,696 Total reclassifications for the period (net of tax) $142,693 (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) for Entergy for the nine months ended September 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $177,129 Competitive business operating revenues Interest rate swaps (1,533 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 175,596 (61,458 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $114,138 Pension and other postretirement liabilities Amortization of prior-service credit $17,956 (a) Amortization of loss (52,764 ) (a) Total amortization (34,808 ) 11,498 Income taxes Total amortization (net of tax) ($23,310 ) Net unrealized investment gain (loss) Realized gain (loss) $40,457 Interest and investment income (19,824 ) Income taxes Total realized investment gain (loss) (net of tax) $20,633 Total reclassifications for the period (net of tax) $111,461 (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) for Entergy Louisiana for the three months ended September 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,947 (a) Amortization of loss (1,570 ) (a) Total amortization 377 (145 ) Income taxes Total amortization (net of tax) 232 Total reclassifications for the period (net of tax) $232 (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) for Entergy Louisiana for the three months ended September 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,866 (a) Amortization of loss (2,536 ) (a) Total amortization (670 ) 258 Income taxes Total amortization (net of tax) (412 ) Total reclassifications for the period (net of tax) ($412 ) (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) for Entergy Louisiana for the nine months ended September 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,841 (a) Amortization of loss (4,712 ) (a) Total amortization 1,129 (404 ) Income taxes Total amortization (net of tax) 725 Total reclassifications for the period (net of tax) $725 (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) for Entergy Louisiana for the nine months ended September 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,599 (a) Amortization of loss (7,606 ) (a) Total amortization (2,007 ) 803 Income taxes Total amortization (net of tax) (1,204 ) Total reclassifications for the period (net of tax) ($1,204 ) (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, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and System Energy) Common Stock Earnings (loss) per Share The following table presents Entergy’s basic and diluted earnings (loss) per share calculations included on the consolidated statements of operations: For the Three Months Ended September 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings (loss) per share Income Shares $/share Loss Shares $/share Net income (loss) attributable to Entergy Corporation $388.2 179.0 $2.17 ($723.0 ) 179.2 ($4.04 ) Average dilutive effect of: Stock options 0.3 — — — Other equity plans 0.7 (0.01 ) — — Diluted earnings (loss) per share $388.2 180.0 $2.16 ($723.0 ) 179.2 ($4.04 ) The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 3.5 million for the three months ended September 30, 2016 and approximately 7.4 million for the three months ended September 30, 2015 . For the Nine Months Ended September 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings (loss) per share Income Shares $/share Loss Shares $/share Net income (loss) attributable to Entergy Corporation $1,185.4 178.8 $6.63 ($276.1 ) 179.4 ($1.54 ) Average dilutive effect of: Stock options 0.2 (0.01 ) — — Other equity plans 0.5 (0.02 ) — — Diluted earnings (loss) per share $1,185.4 179.5 $6.60 ($276.1 ) 179.4 ($1.54 ) The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 4.6 million for the nine months ended September 30, 2016 and approximately 7.4 million for the nine months ended September 30, 2015 . 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. In May 2016, System Energy paid its parent, Entergy Corporation, a $40 million distribution out of its common stock. Treasury Stock During the nine months ended September 30, 2016 , Entergy Corporation issued 738,579 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, 2016 . Preferred Stock In September 2016, Entergy Arkansas redeemed $10 million of its 6.08% Series preferred stock and $75 million of its 6.45% Series preferred stock. In October 2016, Entergy Mississippi redeemed $30 million of its 6.25% Series preferred stock. Retained Earnings On October 28, 2016, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.87 per share, payable on December 1, 2016, to holders of record as of November 10, 2016. 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, 2016 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, July 1, 2016 $32,423 ($453,999 ) $411,581 $840 ($9,155 ) Other comprehensive income (loss) before reclassifications 45,162 — 23,039 (92 ) 68,109 Amounts reclassified from accumulated other comprehensive income (loss) (24,190 ) 5,044 (1,672 ) — (20,818 ) Net other comprehensive income (loss) for the period 20,972 5,044 21,367 (92 ) 47,291 Ending balance, September 30, 2016 $53,395 ($448,955 ) $432,948 $748 $38,136 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2015 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, July 1, 2015 $107,484 ($553,903 ) $396,818 $2,785 ($46,816 ) Other comprehensive income (loss) before reclassifications 31,620 — (50,760 ) (469 ) (19,609 ) Amounts reclassified from accumulated other comprehensive income (loss) (55,604 ) 7,437 (3,206 ) — (51,373 ) Net other comprehensive income (loss) for the period (23,984 ) 7,437 (53,966 ) (469 ) (70,982 ) Ending balance, September 30, 2015 $83,500 ($546,466 ) $342,852 $2,316 ($117,798 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2016 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, 2016 $105,970 ($466,604 ) $367,557 $2,028 $8,951 Other comprehensive income (loss) before reclassifications 101,071 — 72,087 (1,280 ) 171,878 Amounts reclassified from accumulated other comprehensive income (loss) (153,646 ) 17,649 (6,696 ) — (142,693 ) Net other comprehensive income (loss) for the period (52,575 ) 17,649 65,391 (1,280 ) 29,185 Ending balance, September 30, 2016 $53,395 ($448,955 ) $432,948 $748 $38,136 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2015 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, 2015 $98,118 ($569,789 ) $426,695 $2,669 ($42,307 ) Other comprehensive income (loss) before reclassifications 99,520 13 (63,210 ) (353 ) 35,970 Amounts reclassified from accumulated other comprehensive income (loss) (114,138 ) 23,310 (20,633 ) — (111,461 ) Net other comprehensive income (loss) for the period (14,618 ) 23,323 (83,843 ) (353 ) (75,491 ) Ending balance, September 30, 2015 $83,500 ($546,466 ) $342,852 $2,316 ($117,798 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2016 : Pension and Other (In Thousands) Beginning balance July 1, 2016 ($56,905 ) Amounts reclassified from accumulated other (232 ) Net other comprehensive income (loss) for the period (232 ) Ending balance, September 30, 2016 ($57,137 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2015 : Pension and Other (In Thousands) Beginning balance July 1, 2015 ($78,431 ) Amounts reclassified from accumulated other 412 Net other comprehensive income (loss) for the period 412 Ending balance, September 30, 2015 ($78,019 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2016 : Pension and Other (In Thousands) Beginning balance, January 1, 2016 ($56,412 ) Amounts reclassified from accumulated other (725 ) Net other comprehensive income (loss) for the period (725 ) Ending balance, September 30, 2016 ($57,137 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2015 : Pension and Other (In Thousands) Beginning balance, January 1, 2015 ($79,223 ) Amounts reclassified from accumulated other 1,204 Net other comprehensive income (loss) for the period 1,204 Ending balance, September 30, 2015 ($78,019 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended September 30, 2016 are as follows: Amounts reclassified from AOCI Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $37,550 Competitive business operating revenues Interest rate swaps (334 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 37,216 (13,026 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $24,190 Pension and other postretirement liabilities Amortization of prior-service credit $7,354 (a) Amortization of loss (15,183 ) (a) Settlement loss (1,279 ) (a) Total amortization (9,108 ) 4,064 Income taxes Total amortization (net of tax) ($5,044 ) Net unrealized investment gain (loss) Realized gain (loss) $3,279 Interest and investment income (1,607 ) Income taxes Total realized investment gain (loss) (net of tax) $1,672 Total reclassifications for the period (net of tax) $20,818 (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) for Entergy for the three months ended September 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $86,020 Competitive business operating revenues Interest rate swaps (477 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 85,543 (29,939 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $55,604 Pension and other postretirement liabilities Amortization of prior-service credit $5,985 (a) Amortization of loss (17,588 ) (a) Total amortization (11,603 ) 4,166 Income taxes Total amortization (net of tax) ($7,437 ) Net unrealized investment gain (loss) Realized gain (loss) $6,286 Interest and investment income (3,080 ) Income taxes Total realized investment gain (loss) (net of tax) $3,206 Total reclassifications for the period (net of tax) $51,373 (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) for Entergy for the nine months ended September 30, 2016 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $237,483 Competitive business operating revenues Interest rate swaps (1,104 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 236,379 (82,733 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $153,646 Pension and other postretirement liabilities Amortization of prior-service credit $22,064 (a) Amortization of loss (45,535 ) (a) Settlement loss (1,279 ) (a) Total amortization (24,750 ) 7,101 Income taxes Total amortization (net of tax) ($17,649 ) Net unrealized investment gain (loss) Realized gain (loss) $13,129 Interest and investment income (6,433 ) Income taxes Total realized investment gain (loss) (net of tax) $6,696 Total reclassifications for the period (net of tax) $142,693 (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) for Entergy for the nine months ended September 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $177,129 Competitive business operating revenues Interest rate swaps (1,533 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 175,596 (61,458 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $114,138 Pension and other postretirement liabilities Amortization of prior-service credit $17,956 (a) Amortization of loss (52,764 ) (a) Total amortization (34,808 ) 11,498 Income taxes Total amortization (net of tax) ($23,310 ) Net unrealized investment gain (loss) Realized gain (loss) $40,457 Interest and investment income (19,824 ) Income taxes Total realized investment gain (loss) (net of tax) $20,633 Total reclassifications for the period (net of tax) $111,461 (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) for Entergy Louisiana for the three months ended September 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,947 (a) Amortization of loss (1,570 ) (a) Total amortization 377 (145 ) Income taxes Total amortization (net of tax) 232 Total reclassifications for the period (net of tax) $232 (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) for Entergy Louisiana for the three months ended September 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,866 (a) Amortization of loss (2,536 ) (a) Total amortization (670 ) 258 Income taxes Total amortization (net of tax) (412 ) Total reclassifications for the period (net of tax) ($412 ) (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) for Entergy Louisiana for the nine months ended September 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,841 (a) Amortization of loss (4,712 ) (a) Total amortization 1,129 (404 ) Income taxes Total amortization (net of tax) 725 Total reclassifications for the period (net of tax) $725 (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) for Entergy Louisiana for the nine months ended September 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,599 (a) Amortization of loss (7,606 ) (a) Total amortization (2,007 ) 803 Income taxes Total amortization (net of tax) (1,204 ) Total reclassifications for the period (net of tax) ($1,204 ) (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 Mississippi [Member]
Equity	EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and System Energy) Common Stock Earnings (loss) per Share The following table presents Entergy’s basic and diluted earnings (loss) per share calculations included on the consolidated statements of operations: For the Three Months Ended September 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings (loss) per share Income Shares $/share Loss Shares $/share Net income (loss) attributable to Entergy Corporation $388.2 179.0 $2.17 ($723.0 ) 179.2 ($4.04 ) Average dilutive effect of: Stock options 0.3 — — — Other equity plans 0.7 (0.01 ) — — Diluted earnings (loss) per share $388.2 180.0 $2.16 ($723.0 ) 179.2 ($4.04 ) The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 3.5 million for the three months ended September 30, 2016 and approximately 7.4 million for the three months ended September 30, 2015 . For the Nine Months Ended September 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings (loss) per share Income Shares $/share Loss Shares $/share Net income (loss) attributable to Entergy Corporation $1,185.4 178.8 $6.63 ($276.1 ) 179.4 ($1.54 ) Average dilutive effect of: Stock options 0.2 (0.01 ) — — Other equity plans 0.5 (0.02 ) — — Diluted earnings (loss) per share $1,185.4 179.5 $6.60 ($276.1 ) 179.4 ($1.54 ) The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 4.6 million for the nine months ended September 30, 2016 and approximately 7.4 million for the nine months ended September 30, 2015 . 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. In May 2016, System Energy paid its parent, Entergy Corporation, a $40 million distribution out of its common stock. Treasury Stock During the nine months ended September 30, 2016 , Entergy Corporation issued 738,579 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, 2016 . Preferred Stock In September 2016, Entergy Arkansas redeemed $10 million of its 6.08% Series preferred stock and $75 million of its 6.45% Series preferred stock. In October 2016, Entergy Mississippi redeemed $30 million of its 6.25% Series preferred stock. Retained Earnings On October 28, 2016, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.87 per share, payable on December 1, 2016, to holders of record as of November 10, 2016. 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, 2016 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, July 1, 2016 $32,423 ($453,999 ) $411,581 $840 ($9,155 ) Other comprehensive income (loss) before reclassifications 45,162 — 23,039 (92 ) 68,109 Amounts reclassified from accumulated other comprehensive income (loss) (24,190 ) 5,044 (1,672 ) — (20,818 ) Net other comprehensive income (loss) for the period 20,972 5,044 21,367 (92 ) 47,291 Ending balance, September 30, 2016 $53,395 ($448,955 ) $432,948 $748 $38,136 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2015 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, July 1, 2015 $107,484 ($553,903 ) $396,818 $2,785 ($46,816 ) Other comprehensive income (loss) before reclassifications 31,620 — (50,760 ) (469 ) (19,609 ) Amounts reclassified from accumulated other comprehensive income (loss) (55,604 ) 7,437 (3,206 ) — (51,373 ) Net other comprehensive income (loss) for the period (23,984 ) 7,437 (53,966 ) (469 ) (70,982 ) Ending balance, September 30, 2015 $83,500 ($546,466 ) $342,852 $2,316 ($117,798 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2016 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, 2016 $105,970 ($466,604 ) $367,557 $2,028 $8,951 Other comprehensive income (loss) before reclassifications 101,071 — 72,087 (1,280 ) 171,878 Amounts reclassified from accumulated other comprehensive income (loss) (153,646 ) 17,649 (6,696 ) — (142,693 ) Net other comprehensive income (loss) for the period (52,575 ) 17,649 65,391 (1,280 ) 29,185 Ending balance, September 30, 2016 $53,395 ($448,955 ) $432,948 $748 $38,136 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2015 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, 2015 $98,118 ($569,789 ) $426,695 $2,669 ($42,307 ) Other comprehensive income (loss) before reclassifications 99,520 13 (63,210 ) (353 ) 35,970 Amounts reclassified from accumulated other comprehensive income (loss) (114,138 ) 23,310 (20,633 ) — (111,461 ) Net other comprehensive income (loss) for the period (14,618 ) 23,323 (83,843 ) (353 ) (75,491 ) Ending balance, September 30, 2015 $83,500 ($546,466 ) $342,852 $2,316 ($117,798 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2016 : Pension and Other (In Thousands) Beginning balance July 1, 2016 ($56,905 ) Amounts reclassified from accumulated other (232 ) Net other comprehensive income (loss) for the period (232 ) Ending balance, September 30, 2016 ($57,137 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2015 : Pension and Other (In Thousands) Beginning balance July 1, 2015 ($78,431 ) Amounts reclassified from accumulated other 412 Net other comprehensive income (loss) for the period 412 Ending balance, September 30, 2015 ($78,019 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2016 : Pension and Other (In Thousands) Beginning balance, January 1, 2016 ($56,412 ) Amounts reclassified from accumulated other (725 ) Net other comprehensive income (loss) for the period (725 ) Ending balance, September 30, 2016 ($57,137 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2015 : Pension and Other (In Thousands) Beginning balance, January 1, 2015 ($79,223 ) Amounts reclassified from accumulated other 1,204 Net other comprehensive income (loss) for the period 1,204 Ending balance, September 30, 2015 ($78,019 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended September 30, 2016 are as follows: Amounts reclassified from AOCI Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $37,550 Competitive business operating revenues Interest rate swaps (334 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 37,216 (13,026 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $24,190 Pension and other postretirement liabilities Amortization of prior-service credit $7,354 (a) Amortization of loss (15,183 ) (a) Settlement loss (1,279 ) (a) Total amortization (9,108 ) 4,064 Income taxes Total amortization (net of tax) ($5,044 ) Net unrealized investment gain (loss) Realized gain (loss) $3,279 Interest and investment income (1,607 ) Income taxes Total realized investment gain (loss) (net of tax) $1,672 Total reclassifications for the period (net of tax) $20,818 (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) for Entergy for the three months ended September 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $86,020 Competitive business operating revenues Interest rate swaps (477 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 85,543 (29,939 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $55,604 Pension and other postretirement liabilities Amortization of prior-service credit $5,985 (a) Amortization of loss (17,588 ) (a) Total amortization (11,603 ) 4,166 Income taxes Total amortization (net of tax) ($7,437 ) Net unrealized investment gain (loss) Realized gain (loss) $6,286 Interest and investment income (3,080 ) Income taxes Total realized investment gain (loss) (net of tax) $3,206 Total reclassifications for the period (net of tax) $51,373 (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) for Entergy for the nine months ended September 30, 2016 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $237,483 Competitive business operating revenues Interest rate swaps (1,104 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 236,379 (82,733 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $153,646 Pension and other postretirement liabilities Amortization of prior-service credit $22,064 (a) Amortization of loss (45,535 ) (a) Settlement loss (1,279 ) (a) Total amortization (24,750 ) 7,101 Income taxes Total amortization (net of tax) ($17,649 ) Net unrealized investment gain (loss) Realized gain (loss) $13,129 Interest and investment income (6,433 ) Income taxes Total realized investment gain (loss) (net of tax) $6,696 Total reclassifications for the period (net of tax) $142,693 (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) for Entergy for the nine months ended September 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $177,129 Competitive business operating revenues Interest rate swaps (1,533 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 175,596 (61,458 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $114,138 Pension and other postretirement liabilities Amortization of prior-service credit $17,956 (a) Amortization of loss (52,764 ) (a) Total amortization (34,808 ) 11,498 Income taxes Total amortization (net of tax) ($23,310 ) Net unrealized investment gain (loss) Realized gain (loss) $40,457 Interest and investment income (19,824 ) Income taxes Total realized investment gain (loss) (net of tax) $20,633 Total reclassifications for the period (net of tax) $111,461 (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) for Entergy Louisiana for the three months ended September 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,947 (a) Amortization of loss (1,570 ) (a) Total amortization 377 (145 ) Income taxes Total amortization (net of tax) 232 Total reclassifications for the period (net of tax) $232 (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) for Entergy Louisiana for the three months ended September 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,866 (a) Amortization of loss (2,536 ) (a) Total amortization (670 ) 258 Income taxes Total amortization (net of tax) (412 ) Total reclassifications for the period (net of tax) ($412 ) (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) for Entergy Louisiana for the nine months ended September 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,841 (a) Amortization of loss (4,712 ) (a) Total amortization 1,129 (404 ) Income taxes Total amortization (net of tax) 725 Total reclassifications for the period (net of tax) $725 (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) for Entergy Louisiana for the nine months ended September 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,599 (a) Amortization of loss (7,606 ) (a) Total amortization (2,007 ) 803 Income taxes Total amortization (net of tax) (1,204 ) Total reclassifications for the period (net of tax) ($1,204 ) (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.
System Energy [Member]
Equity	EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and System Energy) Common Stock Earnings (loss) per Share The following table presents Entergy’s basic and diluted earnings (loss) per share calculations included on the consolidated statements of operations: For the Three Months Ended September 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings (loss) per share Income Shares $/share Loss Shares $/share Net income (loss) attributable to Entergy Corporation $388.2 179.0 $2.17 ($723.0 ) 179.2 ($4.04 ) Average dilutive effect of: Stock options 0.3 — — — Other equity plans 0.7 (0.01 ) — — Diluted earnings (loss) per share $388.2 180.0 $2.16 ($723.0 ) 179.2 ($4.04 ) The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 3.5 million for the three months ended September 30, 2016 and approximately 7.4 million for the three months ended September 30, 2015 . For the Nine Months Ended September 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings (loss) per share Income Shares $/share Loss Shares $/share Net income (loss) attributable to Entergy Corporation $1,185.4 178.8 $6.63 ($276.1 ) 179.4 ($1.54 ) Average dilutive effect of: Stock options 0.2 (0.01 ) — — Other equity plans 0.5 (0.02 ) — — Diluted earnings (loss) per share $1,185.4 179.5 $6.60 ($276.1 ) 179.4 ($1.54 ) The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 4.6 million for the nine months ended September 30, 2016 and approximately 7.4 million for the nine months ended September 30, 2015 . 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. In May 2016, System Energy paid its parent, Entergy Corporation, a $40 million distribution out of its common stock. Treasury Stock During the nine months ended September 30, 2016 , Entergy Corporation issued 738,579 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, 2016 . Preferred Stock In September 2016, Entergy Arkansas redeemed $10 million of its 6.08% Series preferred stock and $75 million of its 6.45% Series preferred stock. In October 2016, Entergy Mississippi redeemed $30 million of its 6.25% Series preferred stock. Retained Earnings On October 28, 2016, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.87 per share, payable on December 1, 2016, to holders of record as of November 10, 2016. 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, 2016 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, July 1, 2016 $32,423 ($453,999 ) $411,581 $840 ($9,155 ) Other comprehensive income (loss) before reclassifications 45,162 — 23,039 (92 ) 68,109 Amounts reclassified from accumulated other comprehensive income (loss) (24,190 ) 5,044 (1,672 ) — (20,818 ) Net other comprehensive income (loss) for the period 20,972 5,044 21,367 (92 ) 47,291 Ending balance, September 30, 2016 $53,395 ($448,955 ) $432,948 $748 $38,136 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2015 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, July 1, 2015 $107,484 ($553,903 ) $396,818 $2,785 ($46,816 ) Other comprehensive income (loss) before reclassifications 31,620 — (50,760 ) (469 ) (19,609 ) Amounts reclassified from accumulated other comprehensive income (loss) (55,604 ) 7,437 (3,206 ) — (51,373 ) Net other comprehensive income (loss) for the period (23,984 ) 7,437 (53,966 ) (469 ) (70,982 ) Ending balance, September 30, 2015 $83,500 ($546,466 ) $342,852 $2,316 ($117,798 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2016 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, 2016 $105,970 ($466,604 ) $367,557 $2,028 $8,951 Other comprehensive income (loss) before reclassifications 101,071 — 72,087 (1,280 ) 171,878 Amounts reclassified from accumulated other comprehensive income (loss) (153,646 ) 17,649 (6,696 ) — (142,693 ) Net other comprehensive income (loss) for the period (52,575 ) 17,649 65,391 (1,280 ) 29,185 Ending balance, September 30, 2016 $53,395 ($448,955 ) $432,948 $748 $38,136 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2015 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, 2015 $98,118 ($569,789 ) $426,695 $2,669 ($42,307 ) Other comprehensive income (loss) before reclassifications 99,520 13 (63,210 ) (353 ) 35,970 Amounts reclassified from accumulated other comprehensive income (loss) (114,138 ) 23,310 (20,633 ) — (111,461 ) Net other comprehensive income (loss) for the period (14,618 ) 23,323 (83,843 ) (353 ) (75,491 ) Ending balance, September 30, 2015 $83,500 ($546,466 ) $342,852 $2,316 ($117,798 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2016 : Pension and Other (In Thousands) Beginning balance July 1, 2016 ($56,905 ) Amounts reclassified from accumulated other (232 ) Net other comprehensive income (loss) for the period (232 ) Ending balance, September 30, 2016 ($57,137 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2015 : Pension and Other (In Thousands) Beginning balance July 1, 2015 ($78,431 ) Amounts reclassified from accumulated other 412 Net other comprehensive income (loss) for the period 412 Ending balance, September 30, 2015 ($78,019 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2016 : Pension and Other (In Thousands) Beginning balance, January 1, 2016 ($56,412 ) Amounts reclassified from accumulated other (725 ) Net other comprehensive income (loss) for the period (725 ) Ending balance, September 30, 2016 ($57,137 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2015 : Pension and Other (In Thousands) Beginning balance, January 1, 2015 ($79,223 ) Amounts reclassified from accumulated other 1,204 Net other comprehensive income (loss) for the period 1,204 Ending balance, September 30, 2015 ($78,019 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended September 30, 2016 are as follows: Amounts reclassified from AOCI Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $37,550 Competitive business operating revenues Interest rate swaps (334 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 37,216 (13,026 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $24,190 Pension and other postretirement liabilities Amortization of prior-service credit $7,354 (a) Amortization of loss (15,183 ) (a) Settlement loss (1,279 ) (a) Total amortization (9,108 ) 4,064 Income taxes Total amortization (net of tax) ($5,044 ) Net unrealized investment gain (loss) Realized gain (loss) $3,279 Interest and investment income (1,607 ) Income taxes Total realized investment gain (loss) (net of tax) $1,672 Total reclassifications for the period (net of tax) $20,818 (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) for Entergy for the three months ended September 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $86,020 Competitive business operating revenues Interest rate swaps (477 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 85,543 (29,939 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $55,604 Pension and other postretirement liabilities Amortization of prior-service credit $5,985 (a) Amortization of loss (17,588 ) (a) Total amortization (11,603 ) 4,166 Income taxes Total amortization (net of tax) ($7,437 ) Net unrealized investment gain (loss) Realized gain (loss) $6,286 Interest and investment income (3,080 ) Income taxes Total realized investment gain (loss) (net of tax) $3,206 Total reclassifications for the period (net of tax) $51,373 (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) for Entergy for the nine months ended September 30, 2016 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $237,483 Competitive business operating revenues Interest rate swaps (1,104 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 236,379 (82,733 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $153,646 Pension and other postretirement liabilities Amortization of prior-service credit $22,064 (a) Amortization of loss (45,535 ) (a) Settlement loss (1,279 ) (a) Total amortization (24,750 ) 7,101 Income taxes Total amortization (net of tax) ($17,649 ) Net unrealized investment gain (loss) Realized gain (loss) $13,129 Interest and investment income (6,433 ) Income taxes Total realized investment gain (loss) (net of tax) $6,696 Total reclassifications for the period (net of tax) $142,693 (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) for Entergy for the nine months ended September 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $177,129 Competitive business operating revenues Interest rate swaps (1,533 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 175,596 (61,458 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $114,138 Pension and other postretirement liabilities Amortization of prior-service credit $17,956 (a) Amortization of loss (52,764 ) (a) Total amortization (34,808 ) 11,498 Income taxes Total amortization (net of tax) ($23,310 ) Net unrealized investment gain (loss) Realized gain (loss) $40,457 Interest and investment income (19,824 ) Income taxes Total realized investment gain (loss) (net of tax) $20,633 Total reclassifications for the period (net of tax) $111,461 (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) for Entergy Louisiana for the three months ended September 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,947 (a) Amortization of loss (1,570 ) (a) Total amortization 377 (145 ) Income taxes Total amortization (net of tax) 232 Total reclassifications for the period (net of tax) $232 (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) for Entergy Louisiana for the three months ended September 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,866 (a) Amortization of loss (2,536 ) (a) Total amortization (670 ) 258 Income taxes Total amortization (net of tax) (412 ) Total reclassifications for the period (net of tax) ($412 ) (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) for Entergy Louisiana for the nine months ended September 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,841 (a) Amortization of loss (4,712 ) (a) Total amortization 1,129 (404 ) Income taxes Total amortization (net of tax) 725 Total reclassifications for the period (net of tax) $725 (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) for Entergy Louisiana for the nine months ended September 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,599 (a) Amortization of loss (7,606 ) (a) Total amortization (2,007 ) 803 Income taxes Total amortization (net of tax) (1,204 ) Total reclassifications for the period (net of tax) ($1,204 ) (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, 2016
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 August 2021. Entergy Corporation also has the ability to issue letters of credit against 50% 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, 2016 was 2.24% 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, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $180 $6 $3,314 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 $1.5 billion . At September 30, 2016 , Entergy Corporation had $264 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2016 was 1.14% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2016 Letters of Credit Outstanding as of September 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.77% $— $— Entergy Arkansas August 2021 $150 million (c) 1.77% $— $— Entergy Louisiana August 2021 $350 million (d) 1.77% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 2.02% $— $— Entergy Mississippi May 2017 $35 million (e) 2.02% $— $— Entergy Mississippi May 2017 $20 million (e) 2.02% $— $— Entergy Mississippi May 2017 $10 million (e) 2.02% $— $— Entergy New Orleans November 2018 $25 million (f) 2.27% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.02% $— $4.7 million (a) The interest rate is the rate as of September 30, 2016 that would most likely apply 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 allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations related to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2016 Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $16.4 million Entergy Mississippi $40 million 0.70% $10.2 million Entergy New Orleans $15 million 0.75% $12.9 million Entergy Texas $50 million 0.70% $16.0 million 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, 2017. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from the money pool 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, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $49 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $12 System Energy $200 $— Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2017. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2018. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through June 2018. Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation which expires in January 2018. In the first quarter 2016, Entergy Nuclear Vermont Yankee increased the borrowing capacity of its credit facility to $100 million . 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, 2016 , $41.5 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2016 was 2.19% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also has an uncommitted credit facility guaranteed by Entergy Corporation with a borrowing capacity of $85 million which expires in January 2018. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides an additional funding source to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. As of September 30, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of September 30, 2016 that would most likely apply to outstanding borrowings under the facility was 2.27% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 18 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 issue commercial paper, details of which follow as of September 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.15% $47.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 2.14% $42.0 (b) System Energy VIE May 2019 $120 2.13% $80.0 (b) (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. (b) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are currently 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, 2016 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Louisiana River Bend VIE 3.25% Series Q due July 2017 $75 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.25% Series G due July 2017 $25 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million System Energy VIE 4.02% Series H due February 2017 $50 million System Energy VIE 3.78% Series I due October 2018 $85 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 Redemptions (Entergy Corporation) In August 2016, Entergy Corporation issued $750 million of 2.95% Series senior notes due September 2026. Entergy Corporation used the proceeds to repay a portion of its commercial paper outstanding and to repay borrowings under the Entergy Corporation credit facility, and plans to use the remainder of the proceeds to pay, prior to maturity, its $500 million of 4.7% Series senior notes due January 2017. (Entergy Arkansas) In January 2016, Entergy Arkansas issued $325 million of 3.5% Series first mortgage bonds due April 2026. Entergy Arkansas used the proceeds to pay, prior to maturity, its $175 million of 5.66% Series first mortgage bonds due February 2025, and used the remainder of the proceeds, together with other funds, towards the purchase of Power Block 2 at the Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In June 2016, Entergy Arkansas issued $55 million of 3.5% Series first mortgage bonds due April 2026. These bonds were a further issuance of the 3.5% Series first mortgage bonds issued in January 2016. In July 2016, Entergy Arkansas used the proceeds, together with other funds, to pay, prior to maturity, its $60 million of 6.38% Series first mortgage bonds due November 2034 and for general corporate purposes. In July 2016 the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $55 million of 3.23% Series J notes. In August 2016, Entergy Arkansas issued $410 million of 4.875% Series first mortgage bonds due September 2066. Entergy Arkansas used the proceeds, together with other funds, to redeem $10 million of its 6.08% Series preferred stock, to redeem $75 million of its 6.45% Series preferred stock, to pay, prior to maturity, its $225 million of 5.75% Series first mortgage bonds due November 2040, to pay, prior to maturity, its $100 million of 5.9% Series first mortgage bonds due June 2033, and for general corporate purposes. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. These bonds were a further issuance of the 4.95% Series first mortgage bonds issued in November 2014. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, to repay borrowings under its $350 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana issued $425 million of 3.25% Series collateral trust mortgage bonds due April 2028. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana arranged for the issuance by the Louisiana Public Facilities Authority of (i) $83.680 million of 3.375% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016A due September 2028, and (ii) $115 million of 3.50% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016B due June 2030, each of which series is evidenced by a separate series of non-interest bearing collateral trust mortgage bonds of Entergy Louisiana. The proceeds from these issuances were applied in April 2016 to the refunding of $198.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. In March 2016, Entergy Louisiana issued $51.972 million of Waterford Series collateral trust mortgage notes due July 2017 as part of the purchase of the undivided interests in Waterford 3. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction. In March 2016 the Entergy Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $20 million of 3.30% Series F notes. In May 2016, Entergy Louisiana issued $325 million of 3.05% Series collateral trust mortgage bonds due June 2031. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $240 million of 6.2% Series first mortgage bonds due July 2033 and its $85 million of 6.18% Series first mortgage bonds due March 2035, and for general corporate purposes. In August 2016, Entergy Louisiana issued $270 million of 4.875% Series collateral trust mortgage bonds due September 2066. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $118 million of 6.0% Series first mortgage bonds due March 2040, to pay, prior to maturity, its $150 million of 5.875% Series first mortgage bonds due June 2041, and for general corporate purposes. In October 2016, Entergy Louisiana issued $400 million of 2.40% Series collateral trust mortgage bonds due October 2026. Entergy Louisiana plans to use the proceeds to repay amounts outstanding of approximately $57 million on its Waterford 3 lessor debt due January 2017 and for general corporate purposes. See Note 11 to the financial statements herein for discussion of Entergy Louisiana’s purchase of the undivided interests in Waterford 3. (Entergy Mississippi) In May 2016, Entergy Mississippi issued $375 million of 2.85% Series first mortgage bonds due June 2028. Entergy Mississippi used the proceeds to pay, at maturity, its $125 million of 3.25% Series first mortgage bonds due June 2016, to pay, prior to maturity, its $75 million of 6.0% Series first mortgage bonds due November 2032, and its $100 million of 6.25% Series first mortgage bonds due April 2034, and to cause the repayment of the $30 million of 4.90% pollution control revenue bonds due 2022 issued on behalf of Entergy Mississippi, and for general corporate purposes. In September 2016, Entergy Mississippi issued $260 million of 4.90% Series first mortgage bonds due October 2066. In October 2016, Entergy Mississippi used the proceeds, together with other funds, to pay, prior to maturity, its $80 million of 6.2% Series first mortgage bonds due April 2040, to pay, prior to maturity, its $150 million of 6.0% Series first mortgage bonds due May 2051, and to redeem $30 million of its 6.25% Series preferred stock. (Entergy New Orleans) In March 2016, Entergy New Orleans issued $110 million of 5.50% Series first mortgage bonds due April 2066. Entergy New Orleans used the proceeds to repay borrowings from the money pool, to repay borrowings under its $25 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Block 1 of the Union Power Station. See Note 13 to the financial statements for discussion of the Union Power Station purchase. In May 2016, Entergy New Orleans issued $85 million of 4% Series first mortgage bonds due June 2026. Entergy New Orleans used the proceeds to pay, prior to maturity, its $33.271 million of 5.6% Series first mortgage bonds due September 2024, to pay, prior to maturity, its $37.772 million of 5.65% Series first mortgage bonds due September 2029, and for general corporate purposes. (Entergy Texas) In March 2016, Entergy Texas issued $125 million of 2.55% Series first mortgage bonds due June 2021. Entergy Texas used the proceeds for general corporate purposes. (System Energy) In May 2016, System Energy caused the repayment of $22 million of its $156 million of 5.875% pollution control revenue bonds due 2022 issued on behalf of System Energy. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,611,903 $15,424,412 Entergy Arkansas $2,796,059 $2,791,291 Entergy Louisiana $5,407,897 $5,848,345 Entergy Mississippi $1,344,305 $1,409,719 Entergy New Orleans $459,295 $502,194 Entergy Texas $1,521,270 $1,683,655 System Energy $551,023 $543,933 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 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 and are based on prices derived from inputs such as benchmark yields and reported trades. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2015 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,325,930 $13,578,511 Entergy Arkansas $2,629,839 $2,498,108 Entergy Louisiana $4,836,162 $5,018,786 Entergy Mississippi $1,045,085 $1,087,326 Entergy New Orleans $342,880 $351,040 Entergy Texas $1,451,967 $1,590,616 System Energy $572,667 $552,762 (a) The values exclude lease obligations of $109 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $35 million at Entergy, 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 and are based on prices derived from inputs such as benchmark yields and reported trades.
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 August 2021. Entergy Corporation also has the ability to issue letters of credit against 50% 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, 2016 was 2.24% 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, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $180 $6 $3,314 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 $1.5 billion . At September 30, 2016 , Entergy Corporation had $264 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2016 was 1.14% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2016 Letters of Credit Outstanding as of September 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.77% $— $— Entergy Arkansas August 2021 $150 million (c) 1.77% $— $— Entergy Louisiana August 2021 $350 million (d) 1.77% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 2.02% $— $— Entergy Mississippi May 2017 $35 million (e) 2.02% $— $— Entergy Mississippi May 2017 $20 million (e) 2.02% $— $— Entergy Mississippi May 2017 $10 million (e) 2.02% $— $— Entergy New Orleans November 2018 $25 million (f) 2.27% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.02% $— $4.7 million (a) The interest rate is the rate as of September 30, 2016 that would most likely apply 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 allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations related to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2016 Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $16.4 million Entergy Mississippi $40 million 0.70% $10.2 million Entergy New Orleans $15 million 0.75% $12.9 million Entergy Texas $50 million 0.70% $16.0 million 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, 2017. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from the money pool 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, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $49 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $12 System Energy $200 $— Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2017. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2018. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through June 2018. Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation which expires in January 2018. In the first quarter 2016, Entergy Nuclear Vermont Yankee increased the borrowing capacity of its credit facility to $100 million . 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, 2016 , $41.5 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2016 was 2.19% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also has an uncommitted credit facility guaranteed by Entergy Corporation with a borrowing capacity of $85 million which expires in January 2018. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides an additional funding source to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. As of September 30, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of September 30, 2016 that would most likely apply to outstanding borrowings under the facility was 2.27% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 18 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 issue commercial paper, details of which follow as of September 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.15% $47.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 2.14% $42.0 (b) System Energy VIE May 2019 $120 2.13% $80.0 (b) (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. (b) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are currently 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, 2016 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Louisiana River Bend VIE 3.25% Series Q due July 2017 $75 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.25% Series G due July 2017 $25 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million System Energy VIE 4.02% Series H due February 2017 $50 million System Energy VIE 3.78% Series I due October 2018 $85 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 Redemptions (Entergy Corporation) In August 2016, Entergy Corporation issued $750 million of 2.95% Series senior notes due September 2026. Entergy Corporation used the proceeds to repay a portion of its commercial paper outstanding and to repay borrowings under the Entergy Corporation credit facility, and plans to use the remainder of the proceeds to pay, prior to maturity, its $500 million of 4.7% Series senior notes due January 2017. (Entergy Arkansas) In January 2016, Entergy Arkansas issued $325 million of 3.5% Series first mortgage bonds due April 2026. Entergy Arkansas used the proceeds to pay, prior to maturity, its $175 million of 5.66% Series first mortgage bonds due February 2025, and used the remainder of the proceeds, together with other funds, towards the purchase of Power Block 2 at the Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In June 2016, Entergy Arkansas issued $55 million of 3.5% Series first mortgage bonds due April 2026. These bonds were a further issuance of the 3.5% Series first mortgage bonds issued in January 2016. In July 2016, Entergy Arkansas used the proceeds, together with other funds, to pay, prior to maturity, its $60 million of 6.38% Series first mortgage bonds due November 2034 and for general corporate purposes. In July 2016 the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $55 million of 3.23% Series J notes. In August 2016, Entergy Arkansas issued $410 million of 4.875% Series first mortgage bonds due September 2066. Entergy Arkansas used the proceeds, together with other funds, to redeem $10 million of its 6.08% Series preferred stock, to redeem $75 million of its 6.45% Series preferred stock, to pay, prior to maturity, its $225 million of 5.75% Series first mortgage bonds due November 2040, to pay, prior to maturity, its $100 million of 5.9% Series first mortgage bonds due June 2033, and for general corporate purposes. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. These bonds were a further issuance of the 4.95% Series first mortgage bonds issued in November 2014. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, to repay borrowings under its $350 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana issued $425 million of 3.25% Series collateral trust mortgage bonds due April 2028. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana arranged for the issuance by the Louisiana Public Facilities Authority of (i) $83.680 million of 3.375% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016A due September 2028, and (ii) $115 million of 3.50% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016B due June 2030, each of which series is evidenced by a separate series of non-interest bearing collateral trust mortgage bonds of Entergy Louisiana. The proceeds from these issuances were applied in April 2016 to the refunding of $198.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. In March 2016, Entergy Louisiana issued $51.972 million of Waterford Series collateral trust mortgage notes due July 2017 as part of the purchase of the undivided interests in Waterford 3. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction. In March 2016 the Entergy Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $20 million of 3.30% Series F notes. In May 2016, Entergy Louisiana issued $325 million of 3.05% Series collateral trust mortgage bonds due June 2031. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $240 million of 6.2% Series first mortgage bonds due July 2033 and its $85 million of 6.18% Series first mortgage bonds due March 2035, and for general corporate purposes. In August 2016, Entergy Louisiana issued $270 million of 4.875% Series collateral trust mortgage bonds due September 2066. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $118 million of 6.0% Series first mortgage bonds due March 2040, to pay, prior to maturity, its $150 million of 5.875% Series first mortgage bonds due June 2041, and for general corporate purposes. In October 2016, Entergy Louisiana issued $400 million of 2.40% Series collateral trust mortgage bonds due October 2026. Entergy Louisiana plans to use the proceeds to repay amounts outstanding of approximately $57 million on its Waterford 3 lessor debt due January 2017 and for general corporate purposes. See Note 11 to the financial statements herein for discussion of Entergy Louisiana’s purchase of the undivided interests in Waterford 3. (Entergy Mississippi) In May 2016, Entergy Mississippi issued $375 million of 2.85% Series first mortgage bonds due June 2028. Entergy Mississippi used the proceeds to pay, at maturity, its $125 million of 3.25% Series first mortgage bonds due June 2016, to pay, prior to maturity, its $75 million of 6.0% Series first mortgage bonds due November 2032, and its $100 million of 6.25% Series first mortgage bonds due April 2034, and to cause the repayment of the $30 million of 4.90% pollution control revenue bonds due 2022 issued on behalf of Entergy Mississippi, and for general corporate purposes. In September 2016, Entergy Mississippi issued $260 million of 4.90% Series first mortgage bonds due October 2066. In October 2016, Entergy Mississippi used the proceeds, together with other funds, to pay, prior to maturity, its $80 million of 6.2% Series first mortgage bonds due April 2040, to pay, prior to maturity, its $150 million of 6.0% Series first mortgage bonds due May 2051, and to redeem $30 million of its 6.25% Series preferred stock. (Entergy New Orleans) In March 2016, Entergy New Orleans issued $110 million of 5.50% Series first mortgage bonds due April 2066. Entergy New Orleans used the proceeds to repay borrowings from the money pool, to repay borrowings under its $25 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Block 1 of the Union Power Station. See Note 13 to the financial statements for discussion of the Union Power Station purchase. In May 2016, Entergy New Orleans issued $85 million of 4% Series first mortgage bonds due June 2026. Entergy New Orleans used the proceeds to pay, prior to maturity, its $33.271 million of 5.6% Series first mortgage bonds due September 2024, to pay, prior to maturity, its $37.772 million of 5.65% Series first mortgage bonds due September 2029, and for general corporate purposes. (Entergy Texas) In March 2016, Entergy Texas issued $125 million of 2.55% Series first mortgage bonds due June 2021. Entergy Texas used the proceeds for general corporate purposes. (System Energy) In May 2016, System Energy caused the repayment of $22 million of its $156 million of 5.875% pollution control revenue bonds due 2022 issued on behalf of System Energy. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,611,903 $15,424,412 Entergy Arkansas $2,796,059 $2,791,291 Entergy Louisiana $5,407,897 $5,848,345 Entergy Mississippi $1,344,305 $1,409,719 Entergy New Orleans $459,295 $502,194 Entergy Texas $1,521,270 $1,683,655 System Energy $551,023 $543,933 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 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 and are based on prices derived from inputs such as benchmark yields and reported trades. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2015 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,325,930 $13,578,511 Entergy Arkansas $2,629,839 $2,498,108 Entergy Louisiana $4,836,162 $5,018,786 Entergy Mississippi $1,045,085 $1,087,326 Entergy New Orleans $342,880 $351,040 Entergy Texas $1,451,967 $1,590,616 System Energy $572,667 $552,762 (a) The values exclude lease obligations of $109 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $35 million at Entergy, 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 and are based on prices derived from inputs such as benchmark yields and reported trades.
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 August 2021. Entergy Corporation also has the ability to issue letters of credit against 50% 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, 2016 was 2.24% 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, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $180 $6 $3,314 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 $1.5 billion . At September 30, 2016 , Entergy Corporation had $264 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2016 was 1.14% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2016 Letters of Credit Outstanding as of September 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.77% $— $— Entergy Arkansas August 2021 $150 million (c) 1.77% $— $— Entergy Louisiana August 2021 $350 million (d) 1.77% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 2.02% $— $— Entergy Mississippi May 2017 $35 million (e) 2.02% $— $— Entergy Mississippi May 2017 $20 million (e) 2.02% $— $— Entergy Mississippi May 2017 $10 million (e) 2.02% $— $— Entergy New Orleans November 2018 $25 million (f) 2.27% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.02% $— $4.7 million (a) The interest rate is the rate as of September 30, 2016 that would most likely apply 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 allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations related to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2016 Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $16.4 million Entergy Mississippi $40 million 0.70% $10.2 million Entergy New Orleans $15 million 0.75% $12.9 million Entergy Texas $50 million 0.70% $16.0 million 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, 2017. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from the money pool 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, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $49 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $12 System Energy $200 $— Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2017. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2018. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through June 2018. Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation which expires in January 2018. In the first quarter 2016, Entergy Nuclear Vermont Yankee increased the borrowing capacity of its credit facility to $100 million . 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, 2016 , $41.5 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2016 was 2.19% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also has an uncommitted credit facility guaranteed by Entergy Corporation with a borrowing capacity of $85 million which expires in January 2018. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides an additional funding source to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. As of September 30, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of September 30, 2016 that would most likely apply to outstanding borrowings under the facility was 2.27% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 18 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 issue commercial paper, details of which follow as of September 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.15% $47.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 2.14% $42.0 (b) System Energy VIE May 2019 $120 2.13% $80.0 (b) (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. (b) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are currently 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, 2016 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Louisiana River Bend VIE 3.25% Series Q due July 2017 $75 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.25% Series G due July 2017 $25 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million System Energy VIE 4.02% Series H due February 2017 $50 million System Energy VIE 3.78% Series I due October 2018 $85 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 Redemptions (Entergy Corporation) In August 2016, Entergy Corporation issued $750 million of 2.95% Series senior notes due September 2026. Entergy Corporation used the proceeds to repay a portion of its commercial paper outstanding and to repay borrowings under the Entergy Corporation credit facility, and plans to use the remainder of the proceeds to pay, prior to maturity, its $500 million of 4.7% Series senior notes due January 2017. (Entergy Arkansas) In January 2016, Entergy Arkansas issued $325 million of 3.5% Series first mortgage bonds due April 2026. Entergy Arkansas used the proceeds to pay, prior to maturity, its $175 million of 5.66% Series first mortgage bonds due February 2025, and used the remainder of the proceeds, together with other funds, towards the purchase of Power Block 2 at the Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In June 2016, Entergy Arkansas issued $55 million of 3.5% Series first mortgage bonds due April 2026. These bonds were a further issuance of the 3.5% Series first mortgage bonds issued in January 2016. In July 2016, Entergy Arkansas used the proceeds, together with other funds, to pay, prior to maturity, its $60 million of 6.38% Series first mortgage bonds due November 2034 and for general corporate purposes. In July 2016 the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $55 million of 3.23% Series J notes. In August 2016, Entergy Arkansas issued $410 million of 4.875% Series first mortgage bonds due September 2066. Entergy Arkansas used the proceeds, together with other funds, to redeem $10 million of its 6.08% Series preferred stock, to redeem $75 million of its 6.45% Series preferred stock, to pay, prior to maturity, its $225 million of 5.75% Series first mortgage bonds due November 2040, to pay, prior to maturity, its $100 million of 5.9% Series first mortgage bonds due June 2033, and for general corporate purposes. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. These bonds were a further issuance of the 4.95% Series first mortgage bonds issued in November 2014. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, to repay borrowings under its $350 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana issued $425 million of 3.25% Series collateral trust mortgage bonds due April 2028. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana arranged for the issuance by the Louisiana Public Facilities Authority of (i) $83.680 million of 3.375% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016A due September 2028, and (ii) $115 million of 3.50% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016B due June 2030, each of which series is evidenced by a separate series of non-interest bearing collateral trust mortgage bonds of Entergy Louisiana. The proceeds from these issuances were applied in April 2016 to the refunding of $198.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. In March 2016, Entergy Louisiana issued $51.972 million of Waterford Series collateral trust mortgage notes due July 2017 as part of the purchase of the undivided interests in Waterford 3. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction. In March 2016 the Entergy Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $20 million of 3.30% Series F notes. In May 2016, Entergy Louisiana issued $325 million of 3.05% Series collateral trust mortgage bonds due June 2031. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $240 million of 6.2% Series first mortgage bonds due July 2033 and its $85 million of 6.18% Series first mortgage bonds due March 2035, and for general corporate purposes. In August 2016, Entergy Louisiana issued $270 million of 4.875% Series collateral trust mortgage bonds due September 2066. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $118 million of 6.0% Series first mortgage bonds due March 2040, to pay, prior to maturity, its $150 million of 5.875% Series first mortgage bonds due June 2041, and for general corporate purposes. In October 2016, Entergy Louisiana issued $400 million of 2.40% Series collateral trust mortgage bonds due October 2026. Entergy Louisiana plans to use the proceeds to repay amounts outstanding of approximately $57 million on its Waterford 3 lessor debt due January 2017 and for general corporate purposes. See Note 11 to the financial statements herein for discussion of Entergy Louisiana’s purchase of the undivided interests in Waterford 3. (Entergy Mississippi) In May 2016, Entergy Mississippi issued $375 million of 2.85% Series first mortgage bonds due June 2028. Entergy Mississippi used the proceeds to pay, at maturity, its $125 million of 3.25% Series first mortgage bonds due June 2016, to pay, prior to maturity, its $75 million of 6.0% Series first mortgage bonds due November 2032, and its $100 million of 6.25% Series first mortgage bonds due April 2034, and to cause the repayment of the $30 million of 4.90% pollution control revenue bonds due 2022 issued on behalf of Entergy Mississippi, and for general corporate purposes. In September 2016, Entergy Mississippi issued $260 million of 4.90% Series first mortgage bonds due October 2066. In October 2016, Entergy Mississippi used the proceeds, together with other funds, to pay, prior to maturity, its $80 million of 6.2% Series first mortgage bonds due April 2040, to pay, prior to maturity, its $150 million of 6.0% Series first mortgage bonds due May 2051, and to redeem $30 million of its 6.25% Series preferred stock. (Entergy New Orleans) In March 2016, Entergy New Orleans issued $110 million of 5.50% Series first mortgage bonds due April 2066. Entergy New Orleans used the proceeds to repay borrowings from the money pool, to repay borrowings under its $25 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Block 1 of the Union Power Station. See Note 13 to the financial statements for discussion of the Union Power Station purchase. In May 2016, Entergy New Orleans issued $85 million of 4% Series first mortgage bonds due June 2026. Entergy New Orleans used the proceeds to pay, prior to maturity, its $33.271 million of 5.6% Series first mortgage bonds due September 2024, to pay, prior to maturity, its $37.772 million of 5.65% Series first mortgage bonds due September 2029, and for general corporate purposes. (Entergy Texas) In March 2016, Entergy Texas issued $125 million of 2.55% Series first mortgage bonds due June 2021. Entergy Texas used the proceeds for general corporate purposes. (System Energy) In May 2016, System Energy caused the repayment of $22 million of its $156 million of 5.875% pollution control revenue bonds due 2022 issued on behalf of System Energy. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,611,903 $15,424,412 Entergy Arkansas $2,796,059 $2,791,291 Entergy Louisiana $5,407,897 $5,848,345 Entergy Mississippi $1,344,305 $1,409,719 Entergy New Orleans $459,295 $502,194 Entergy Texas $1,521,270 $1,683,655 System Energy $551,023 $543,933 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 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 and are based on prices derived from inputs such as benchmark yields and reported trades. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2015 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,325,930 $13,578,511 Entergy Arkansas $2,629,839 $2,498,108 Entergy Louisiana $4,836,162 $5,018,786 Entergy Mississippi $1,045,085 $1,087,326 Entergy New Orleans $342,880 $351,040 Entergy Texas $1,451,967 $1,590,616 System Energy $572,667 $552,762 (a) The values exclude lease obligations of $109 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $35 million at Entergy, 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 and are based on prices derived from inputs such as benchmark yields and reported trades.
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 August 2021. Entergy Corporation also has the ability to issue letters of credit against 50% 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, 2016 was 2.24% 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, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $180 $6 $3,314 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 $1.5 billion . At September 30, 2016 , Entergy Corporation had $264 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2016 was 1.14% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2016 Letters of Credit Outstanding as of September 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.77% $— $— Entergy Arkansas August 2021 $150 million (c) 1.77% $— $— Entergy Louisiana August 2021 $350 million (d) 1.77% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 2.02% $— $— Entergy Mississippi May 2017 $35 million (e) 2.02% $— $— Entergy Mississippi May 2017 $20 million (e) 2.02% $— $— Entergy Mississippi May 2017 $10 million (e) 2.02% $— $— Entergy New Orleans November 2018 $25 million (f) 2.27% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.02% $— $4.7 million (a) The interest rate is the rate as of September 30, 2016 that would most likely apply 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 allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations related to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2016 Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $16.4 million Entergy Mississippi $40 million 0.70% $10.2 million Entergy New Orleans $15 million 0.75% $12.9 million Entergy Texas $50 million 0.70% $16.0 million 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, 2017. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from the money pool 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, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $49 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $12 System Energy $200 $— Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2017. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2018. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through June 2018. Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation which expires in January 2018. In the first quarter 2016, Entergy Nuclear Vermont Yankee increased the borrowing capacity of its credit facility to $100 million . 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, 2016 , $41.5 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2016 was 2.19% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also has an uncommitted credit facility guaranteed by Entergy Corporation with a borrowing capacity of $85 million which expires in January 2018. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides an additional funding source to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. As of September 30, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of September 30, 2016 that would most likely apply to outstanding borrowings under the facility was 2.27% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 18 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 issue commercial paper, details of which follow as of September 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.15% $47.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 2.14% $42.0 (b) System Energy VIE May 2019 $120 2.13% $80.0 (b) (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. (b) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are currently 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, 2016 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Louisiana River Bend VIE 3.25% Series Q due July 2017 $75 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.25% Series G due July 2017 $25 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million System Energy VIE 4.02% Series H due February 2017 $50 million System Energy VIE 3.78% Series I due October 2018 $85 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 Redemptions (Entergy Corporation) In August 2016, Entergy Corporation issued $750 million of 2.95% Series senior notes due September 2026. Entergy Corporation used the proceeds to repay a portion of its commercial paper outstanding and to repay borrowings under the Entergy Corporation credit facility, and plans to use the remainder of the proceeds to pay, prior to maturity, its $500 million of 4.7% Series senior notes due January 2017. (Entergy Arkansas) In January 2016, Entergy Arkansas issued $325 million of 3.5% Series first mortgage bonds due April 2026. Entergy Arkansas used the proceeds to pay, prior to maturity, its $175 million of 5.66% Series first mortgage bonds due February 2025, and used the remainder of the proceeds, together with other funds, towards the purchase of Power Block 2 at the Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In June 2016, Entergy Arkansas issued $55 million of 3.5% Series first mortgage bonds due April 2026. These bonds were a further issuance of the 3.5% Series first mortgage bonds issued in January 2016. In July 2016, Entergy Arkansas used the proceeds, together with other funds, to pay, prior to maturity, its $60 million of 6.38% Series first mortgage bonds due November 2034 and for general corporate purposes. In July 2016 the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $55 million of 3.23% Series J notes. In August 2016, Entergy Arkansas issued $410 million of 4.875% Series first mortgage bonds due September 2066. Entergy Arkansas used the proceeds, together with other funds, to redeem $10 million of its 6.08% Series preferred stock, to redeem $75 million of its 6.45% Series preferred stock, to pay, prior to maturity, its $225 million of 5.75% Series first mortgage bonds due November 2040, to pay, prior to maturity, its $100 million of 5.9% Series first mortgage bonds due June 2033, and for general corporate purposes. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. These bonds were a further issuance of the 4.95% Series first mortgage bonds issued in November 2014. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, to repay borrowings under its $350 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana issued $425 million of 3.25% Series collateral trust mortgage bonds due April 2028. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana arranged for the issuance by the Louisiana Public Facilities Authority of (i) $83.680 million of 3.375% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016A due September 2028, and (ii) $115 million of 3.50% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016B due June 2030, each of which series is evidenced by a separate series of non-interest bearing collateral trust mortgage bonds of Entergy Louisiana. The proceeds from these issuances were applied in April 2016 to the refunding of $198.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. In March 2016, Entergy Louisiana issued $51.972 million of Waterford Series collateral trust mortgage notes due July 2017 as part of the purchase of the undivided interests in Waterford 3. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction. In March 2016 the Entergy Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $20 million of 3.30% Series F notes. In May 2016, Entergy Louisiana issued $325 million of 3.05% Series collateral trust mortgage bonds due June 2031. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $240 million of 6.2% Series first mortgage bonds due July 2033 and its $85 million of 6.18% Series first mortgage bonds due March 2035, and for general corporate purposes. In August 2016, Entergy Louisiana issued $270 million of 4.875% Series collateral trust mortgage bonds due September 2066. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $118 million of 6.0% Series first mortgage bonds due March 2040, to pay, prior to maturity, its $150 million of 5.875% Series first mortgage bonds due June 2041, and for general corporate purposes. In October 2016, Entergy Louisiana issued $400 million of 2.40% Series collateral trust mortgage bonds due October 2026. Entergy Louisiana plans to use the proceeds to repay amounts outstanding of approximately $57 million on its Waterford 3 lessor debt due January 2017 and for general corporate purposes. See Note 11 to the financial statements herein for discussion of Entergy Louisiana’s purchase of the undivided interests in Waterford 3. (Entergy Mississippi) In May 2016, Entergy Mississippi issued $375 million of 2.85% Series first mortgage bonds due June 2028. Entergy Mississippi used the proceeds to pay, at maturity, its $125 million of 3.25% Series first mortgage bonds due June 2016, to pay, prior to maturity, its $75 million of 6.0% Series first mortgage bonds due November 2032, and its $100 million of 6.25% Series first mortgage bonds due April 2034, and to cause the repayment of the $30 million of 4.90% pollution control revenue bonds due 2022 issued on behalf of Entergy Mississippi, and for general corporate purposes. In September 2016, Entergy Mississippi issued $260 million of 4.90% Series first mortgage bonds due October 2066. In October 2016, Entergy Mississippi used the proceeds, together with other funds, to pay, prior to maturity, its $80 million of 6.2% Series first mortgage bonds due April 2040, to pay, prior to maturity, its $150 million of 6.0% Series first mortgage bonds due May 2051, and to redeem $30 million of its 6.25% Series preferred stock. (Entergy New Orleans) In March 2016, Entergy New Orleans issued $110 million of 5.50% Series first mortgage bonds due April 2066. Entergy New Orleans used the proceeds to repay borrowings from the money pool, to repay borrowings under its $25 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Block 1 of the Union Power Station. See Note 13 to the financial statements for discussion of the Union Power Station purchase. In May 2016, Entergy New Orleans issued $85 million of 4% Series first mortgage bonds due June 2026. Entergy New Orleans used the proceeds to pay, prior to maturity, its $33.271 million of 5.6% Series first mortgage bonds due September 2024, to pay, prior to maturity, its $37.772 million of 5.65% Series first mortgage bonds due September 2029, and for general corporate purposes. (Entergy Texas) In March 2016, Entergy Texas issued $125 million of 2.55% Series first mortgage bonds due June 2021. Entergy Texas used the proceeds for general corporate purposes. (System Energy) In May 2016, System Energy caused the repayment of $22 million of its $156 million of 5.875% pollution control revenue bonds due 2022 issued on behalf of System Energy. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,611,903 $15,424,412 Entergy Arkansas $2,796,059 $2,791,291 Entergy Louisiana $5,407,897 $5,848,345 Entergy Mississippi $1,344,305 $1,409,719 Entergy New Orleans $459,295 $502,194 Entergy Texas $1,521,270 $1,683,655 System Energy $551,023 $543,933 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 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 and are based on prices derived from inputs such as benchmark yields and reported trades. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2015 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,325,930 $13,578,511 Entergy Arkansas $2,629,839 $2,498,108 Entergy Louisiana $4,836,162 $5,018,786 Entergy Mississippi $1,045,085 $1,087,326 Entergy New Orleans $342,880 $351,040 Entergy Texas $1,451,967 $1,590,616 System Energy $572,667 $552,762 (a) The values exclude lease obligations of $109 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $35 million at Entergy, 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 and are based on prices derived from inputs such as benchmark yields and reported trades.
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 August 2021. Entergy Corporation also has the ability to issue letters of credit against 50% 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, 2016 was 2.24% 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, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $180 $6 $3,314 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 $1.5 billion . At September 30, 2016 , Entergy Corporation had $264 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2016 was 1.14% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2016 Letters of Credit Outstanding as of September 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.77% $— $— Entergy Arkansas August 2021 $150 million (c) 1.77% $— $— Entergy Louisiana August 2021 $350 million (d) 1.77% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 2.02% $— $— Entergy Mississippi May 2017 $35 million (e) 2.02% $— $— Entergy Mississippi May 2017 $20 million (e) 2.02% $— $— Entergy Mississippi May 2017 $10 million (e) 2.02% $— $— Entergy New Orleans November 2018 $25 million (f) 2.27% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.02% $— $4.7 million (a) The interest rate is the rate as of September 30, 2016 that would most likely apply 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 allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations related to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2016 Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $16.4 million Entergy Mississippi $40 million 0.70% $10.2 million Entergy New Orleans $15 million 0.75% $12.9 million Entergy Texas $50 million 0.70% $16.0 million 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, 2017. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from the money pool 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, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $49 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $12 System Energy $200 $— Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2017. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2018. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through June 2018. Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation which expires in January 2018. In the first quarter 2016, Entergy Nuclear Vermont Yankee increased the borrowing capacity of its credit facility to $100 million . 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, 2016 , $41.5 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2016 was 2.19% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also has an uncommitted credit facility guaranteed by Entergy Corporation with a borrowing capacity of $85 million which expires in January 2018. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides an additional funding source to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. As of September 30, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of September 30, 2016 that would most likely apply to outstanding borrowings under the facility was 2.27% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 18 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 issue commercial paper, details of which follow as of September 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.15% $47.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 2.14% $42.0 (b) System Energy VIE May 2019 $120 2.13% $80.0 (b) (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. (b) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are currently 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, 2016 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Louisiana River Bend VIE 3.25% Series Q due July 2017 $75 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.25% Series G due July 2017 $25 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million System Energy VIE 4.02% Series H due February 2017 $50 million System Energy VIE 3.78% Series I due October 2018 $85 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 Redemptions (Entergy Corporation) In August 2016, Entergy Corporation issued $750 million of 2.95% Series senior notes due September 2026. Entergy Corporation used the proceeds to repay a portion of its commercial paper outstanding and to repay borrowings under the Entergy Corporation credit facility, and plans to use the remainder of the proceeds to pay, prior to maturity, its $500 million of 4.7% Series senior notes due January 2017. (Entergy Arkansas) In January 2016, Entergy Arkansas issued $325 million of 3.5% Series first mortgage bonds due April 2026. Entergy Arkansas used the proceeds to pay, prior to maturity, its $175 million of 5.66% Series first mortgage bonds due February 2025, and used the remainder of the proceeds, together with other funds, towards the purchase of Power Block 2 at the Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In June 2016, Entergy Arkansas issued $55 million of 3.5% Series first mortgage bonds due April 2026. These bonds were a further issuance of the 3.5% Series first mortgage bonds issued in January 2016. In July 2016, Entergy Arkansas used the proceeds, together with other funds, to pay, prior to maturity, its $60 million of 6.38% Series first mortgage bonds due November 2034 and for general corporate purposes. In July 2016 the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $55 million of 3.23% Series J notes. In August 2016, Entergy Arkansas issued $410 million of 4.875% Series first mortgage bonds due September 2066. Entergy Arkansas used the proceeds, together with other funds, to redeem $10 million of its 6.08% Series preferred stock, to redeem $75 million of its 6.45% Series preferred stock, to pay, prior to maturity, its $225 million of 5.75% Series first mortgage bonds due November 2040, to pay, prior to maturity, its $100 million of 5.9% Series first mortgage bonds due June 2033, and for general corporate purposes. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. These bonds were a further issuance of the 4.95% Series first mortgage bonds issued in November 2014. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, to repay borrowings under its $350 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana issued $425 million of 3.25% Series collateral trust mortgage bonds due April 2028. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana arranged for the issuance by the Louisiana Public Facilities Authority of (i) $83.680 million of 3.375% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016A due September 2028, and (ii) $115 million of 3.50% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016B due June 2030, each of which series is evidenced by a separate series of non-interest bearing collateral trust mortgage bonds of Entergy Louisiana. The proceeds from these issuances were applied in April 2016 to the refunding of $198.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. In March 2016, Entergy Louisiana issued $51.972 million of Waterford Series collateral trust mortgage notes due July 2017 as part of the purchase of the undivided interests in Waterford 3. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction. In March 2016 the Entergy Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $20 million of 3.30% Series F notes. In May 2016, Entergy Louisiana issued $325 million of 3.05% Series collateral trust mortgage bonds due June 2031. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $240 million of 6.2% Series first mortgage bonds due July 2033 and its $85 million of 6.18% Series first mortgage bonds due March 2035, and for general corporate purposes. In August 2016, Entergy Louisiana issued $270 million of 4.875% Series collateral trust mortgage bonds due September 2066. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $118 million of 6.0% Series first mortgage bonds due March 2040, to pay, prior to maturity, its $150 million of 5.875% Series first mortgage bonds due June 2041, and for general corporate purposes. In October 2016, Entergy Louisiana issued $400 million of 2.40% Series collateral trust mortgage bonds due October 2026. Entergy Louisiana plans to use the proceeds to repay amounts outstanding of approximately $57 million on its Waterford 3 lessor debt due January 2017 and for general corporate purposes. See Note 11 to the financial statements herein for discussion of Entergy Louisiana’s purchase of the undivided interests in Waterford 3. (Entergy Mississippi) In May 2016, Entergy Mississippi issued $375 million of 2.85% Series first mortgage bonds due June 2028. Entergy Mississippi used the proceeds to pay, at maturity, its $125 million of 3.25% Series first mortgage bonds due June 2016, to pay, prior to maturity, its $75 million of 6.0% Series first mortgage bonds due November 2032, and its $100 million of 6.25% Series first mortgage bonds due April 2034, and to cause the repayment of the $30 million of 4.90% pollution control revenue bonds due 2022 issued on behalf of Entergy Mississippi, and for general corporate purposes. In September 2016, Entergy Mississippi issued $260 million of 4.90% Series first mortgage bonds due October 2066. In October 2016, Entergy Mississippi used the proceeds, together with other funds, to pay, prior to maturity, its $80 million of 6.2% Series first mortgage bonds due April 2040, to pay, prior to maturity, its $150 million of 6.0% Series first mortgage bonds due May 2051, and to redeem $30 million of its 6.25% Series preferred stock. (Entergy New Orleans) In March 2016, Entergy New Orleans issued $110 million of 5.50% Series first mortgage bonds due April 2066. Entergy New Orleans used the proceeds to repay borrowings from the money pool, to repay borrowings under its $25 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Block 1 of the Union Power Station. See Note 13 to the financial statements for discussion of the Union Power Station purchase. In May 2016, Entergy New Orleans issued $85 million of 4% Series first mortgage bonds due June 2026. Entergy New Orleans used the proceeds to pay, prior to maturity, its $33.271 million of 5.6% Series first mortgage bonds due September 2024, to pay, prior to maturity, its $37.772 million of 5.65% Series first mortgage bonds due September 2029, and for general corporate purposes. (Entergy Texas) In March 2016, Entergy Texas issued $125 million of 2.55% Series first mortgage bonds due June 2021. Entergy Texas used the proceeds for general corporate purposes. (System Energy) In May 2016, System Energy caused the repayment of $22 million of its $156 million of 5.875% pollution control revenue bonds due 2022 issued on behalf of System Energy. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,611,903 $15,424,412 Entergy Arkansas $2,796,059 $2,791,291 Entergy Louisiana $5,407,897 $5,848,345 Entergy Mississippi $1,344,305 $1,409,719 Entergy New Orleans $459,295 $502,194 Entergy Texas $1,521,270 $1,683,655 System Energy $551,023 $543,933 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 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 and are based on prices derived from inputs such as benchmark yields and reported trades. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2015 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,325,930 $13,578,511 Entergy Arkansas $2,629,839 $2,498,108 Entergy Louisiana $4,836,162 $5,018,786 Entergy Mississippi $1,045,085 $1,087,326 Entergy New Orleans $342,880 $351,040 Entergy Texas $1,451,967 $1,590,616 System Energy $572,667 $552,762 (a) The values exclude lease obligations of $109 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $35 million at Entergy, 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 and are based on prices derived from inputs such as benchmark yields and reported trades.
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 August 2021. Entergy Corporation also has the ability to issue letters of credit against 50% 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, 2016 was 2.24% 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, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $180 $6 $3,314 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 $1.5 billion . At September 30, 2016 , Entergy Corporation had $264 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2016 was 1.14% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2016 Letters of Credit Outstanding as of September 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.77% $— $— Entergy Arkansas August 2021 $150 million (c) 1.77% $— $— Entergy Louisiana August 2021 $350 million (d) 1.77% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 2.02% $— $— Entergy Mississippi May 2017 $35 million (e) 2.02% $— $— Entergy Mississippi May 2017 $20 million (e) 2.02% $— $— Entergy Mississippi May 2017 $10 million (e) 2.02% $— $— Entergy New Orleans November 2018 $25 million (f) 2.27% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.02% $— $4.7 million (a) The interest rate is the rate as of September 30, 2016 that would most likely apply 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 allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations related to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2016 Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $16.4 million Entergy Mississippi $40 million 0.70% $10.2 million Entergy New Orleans $15 million 0.75% $12.9 million Entergy Texas $50 million 0.70% $16.0 million 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, 2017. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from the money pool 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, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $49 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $12 System Energy $200 $— Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2017. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2018. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through June 2018. Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation which expires in January 2018. In the first quarter 2016, Entergy Nuclear Vermont Yankee increased the borrowing capacity of its credit facility to $100 million . 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, 2016 , $41.5 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2016 was 2.19% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also has an uncommitted credit facility guaranteed by Entergy Corporation with a borrowing capacity of $85 million which expires in January 2018. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides an additional funding source to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. As of September 30, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of September 30, 2016 that would most likely apply to outstanding borrowings under the facility was 2.27% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 18 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 issue commercial paper, details of which follow as of September 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.15% $47.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 2.14% $42.0 (b) System Energy VIE May 2019 $120 2.13% $80.0 (b) (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. (b) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are currently 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, 2016 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Louisiana River Bend VIE 3.25% Series Q due July 2017 $75 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.25% Series G due July 2017 $25 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million System Energy VIE 4.02% Series H due February 2017 $50 million System Energy VIE 3.78% Series I due October 2018 $85 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 Redemptions (Entergy Corporation) In August 2016, Entergy Corporation issued $750 million of 2.95% Series senior notes due September 2026. Entergy Corporation used the proceeds to repay a portion of its commercial paper outstanding and to repay borrowings under the Entergy Corporation credit facility, and plans to use the remainder of the proceeds to pay, prior to maturity, its $500 million of 4.7% Series senior notes due January 2017. (Entergy Arkansas) In January 2016, Entergy Arkansas issued $325 million of 3.5% Series first mortgage bonds due April 2026. Entergy Arkansas used the proceeds to pay, prior to maturity, its $175 million of 5.66% Series first mortgage bonds due February 2025, and used the remainder of the proceeds, together with other funds, towards the purchase of Power Block 2 at the Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In June 2016, Entergy Arkansas issued $55 million of 3.5% Series first mortgage bonds due April 2026. These bonds were a further issuance of the 3.5% Series first mortgage bonds issued in January 2016. In July 2016, Entergy Arkansas used the proceeds, together with other funds, to pay, prior to maturity, its $60 million of 6.38% Series first mortgage bonds due November 2034 and for general corporate purposes. In July 2016 the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $55 million of 3.23% Series J notes. In August 2016, Entergy Arkansas issued $410 million of 4.875% Series first mortgage bonds due September 2066. Entergy Arkansas used the proceeds, together with other funds, to redeem $10 million of its 6.08% Series preferred stock, to redeem $75 million of its 6.45% Series preferred stock, to pay, prior to maturity, its $225 million of 5.75% Series first mortgage bonds due November 2040, to pay, prior to maturity, its $100 million of 5.9% Series first mortgage bonds due June 2033, and for general corporate purposes. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. These bonds were a further issuance of the 4.95% Series first mortgage bonds issued in November 2014. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, to repay borrowings under its $350 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana issued $425 million of 3.25% Series collateral trust mortgage bonds due April 2028. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana arranged for the issuance by the Louisiana Public Facilities Authority of (i) $83.680 million of 3.375% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016A due September 2028, and (ii) $115 million of 3.50% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016B due June 2030, each of which series is evidenced by a separate series of non-interest bearing collateral trust mortgage bonds of Entergy Louisiana. The proceeds from these issuances were applied in April 2016 to the refunding of $198.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. In March 2016, Entergy Louisiana issued $51.972 million of Waterford Series collateral trust mortgage notes due July 2017 as part of the purchase of the undivided interests in Waterford 3. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction. In March 2016 the Entergy Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $20 million of 3.30% Series F notes. In May 2016, Entergy Louisiana issued $325 million of 3.05% Series collateral trust mortgage bonds due June 2031. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $240 million of 6.2% Series first mortgage bonds due July 2033 and its $85 million of 6.18% Series first mortgage bonds due March 2035, and for general corporate purposes. In August 2016, Entergy Louisiana issued $270 million of 4.875% Series collateral trust mortgage bonds due September 2066. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $118 million of 6.0% Series first mortgage bonds due March 2040, to pay, prior to maturity, its $150 million of 5.875% Series first mortgage bonds due June 2041, and for general corporate purposes. In October 2016, Entergy Louisiana issued $400 million of 2.40% Series collateral trust mortgage bonds due October 2026. Entergy Louisiana plans to use the proceeds to repay amounts outstanding of approximately $57 million on its Waterford 3 lessor debt due January 2017 and for general corporate purposes. See Note 11 to the financial statements herein for discussion of Entergy Louisiana’s purchase of the undivided interests in Waterford 3. (Entergy Mississippi) In May 2016, Entergy Mississippi issued $375 million of 2.85% Series first mortgage bonds due June 2028. Entergy Mississippi used the proceeds to pay, at maturity, its $125 million of 3.25% Series first mortgage bonds due June 2016, to pay, prior to maturity, its $75 million of 6.0% Series first mortgage bonds due November 2032, and its $100 million of 6.25% Series first mortgage bonds due April 2034, and to cause the repayment of the $30 million of 4.90% pollution control revenue bonds due 2022 issued on behalf of Entergy Mississippi, and for general corporate purposes. In September 2016, Entergy Mississippi issued $260 million of 4.90% Series first mortgage bonds due October 2066. In October 2016, Entergy Mississippi used the proceeds, together with other funds, to pay, prior to maturity, its $80 million of 6.2% Series first mortgage bonds due April 2040, to pay, prior to maturity, its $150 million of 6.0% Series first mortgage bonds due May 2051, and to redeem $30 million of its 6.25% Series preferred stock. (Entergy New Orleans) In March 2016, Entergy New Orleans issued $110 million of 5.50% Series first mortgage bonds due April 2066. Entergy New Orleans used the proceeds to repay borrowings from the money pool, to repay borrowings under its $25 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Block 1 of the Union Power Station. See Note 13 to the financial statements for discussion of the Union Power Station purchase. In May 2016, Entergy New Orleans issued $85 million of 4% Series first mortgage bonds due June 2026. Entergy New Orleans used the proceeds to pay, prior to maturity, its $33.271 million of 5.6% Series first mortgage bonds due September 2024, to pay, prior to maturity, its $37.772 million of 5.65% Series first mortgage bonds due September 2029, and for general corporate purposes. (Entergy Texas) In March 2016, Entergy Texas issued $125 million of 2.55% Series first mortgage bonds due June 2021. Entergy Texas used the proceeds for general corporate purposes. (System Energy) In May 2016, System Energy caused the repayment of $22 million of its $156 million of 5.875% pollution control revenue bonds due 2022 issued on behalf of System Energy. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,611,903 $15,424,412 Entergy Arkansas $2,796,059 $2,791,291 Entergy Louisiana $5,407,897 $5,848,345 Entergy Mississippi $1,344,305 $1,409,719 Entergy New Orleans $459,295 $502,194 Entergy Texas $1,521,270 $1,683,655 System Energy $551,023 $543,933 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 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 and are based on prices derived from inputs such as benchmark yields and reported trades. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2015 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,325,930 $13,578,511 Entergy Arkansas $2,629,839 $2,498,108 Entergy Louisiana $4,836,162 $5,018,786 Entergy Mississippi $1,045,085 $1,087,326 Entergy New Orleans $342,880 $351,040 Entergy Texas $1,451,967 $1,590,616 System Energy $572,667 $552,762 (a) The values exclude lease obligations of $109 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $35 million at Entergy, 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 and are based on prices derived from inputs such as benchmark yields and reported trades.
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 August 2021. Entergy Corporation also has the ability to issue letters of credit against 50% 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, 2016 was 2.24% 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, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $180 $6 $3,314 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 $1.5 billion . At September 30, 2016 , Entergy Corporation had $264 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2016 was 1.14% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2016 Letters of Credit Outstanding as of September 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.77% $— $— Entergy Arkansas August 2021 $150 million (c) 1.77% $— $— Entergy Louisiana August 2021 $350 million (d) 1.77% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 2.02% $— $— Entergy Mississippi May 2017 $35 million (e) 2.02% $— $— Entergy Mississippi May 2017 $20 million (e) 2.02% $— $— Entergy Mississippi May 2017 $10 million (e) 2.02% $— $— Entergy New Orleans November 2018 $25 million (f) 2.27% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.02% $— $4.7 million (a) The interest rate is the rate as of September 30, 2016 that would most likely apply 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 allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations related to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2016 Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $16.4 million Entergy Mississippi $40 million 0.70% $10.2 million Entergy New Orleans $15 million 0.75% $12.9 million Entergy Texas $50 million 0.70% $16.0 million 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, 2017. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from the money pool 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, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $49 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $12 System Energy $200 $— Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2017. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2018. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through June 2018. Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation which expires in January 2018. In the first quarter 2016, Entergy Nuclear Vermont Yankee increased the borrowing capacity of its credit facility to $100 million . 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, 2016 , $41.5 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the nine months ended September 30, 2016 was 2.19% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also has an uncommitted credit facility guaranteed by Entergy Corporation with a borrowing capacity of $85 million which expires in January 2018. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides an additional funding source to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. As of September 30, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of September 30, 2016 that would most likely apply to outstanding borrowings under the facility was 2.27% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 18 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 issue commercial paper, details of which follow as of September 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.15% $47.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 2.14% $42.0 (b) System Energy VIE May 2019 $120 2.13% $80.0 (b) (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. (b) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are currently 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, 2016 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Louisiana River Bend VIE 3.25% Series Q due July 2017 $75 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.25% Series G due July 2017 $25 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million System Energy VIE 4.02% Series H due February 2017 $50 million System Energy VIE 3.78% Series I due October 2018 $85 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 Redemptions (Entergy Corporation) In August 2016, Entergy Corporation issued $750 million of 2.95% Series senior notes due September 2026. Entergy Corporation used the proceeds to repay a portion of its commercial paper outstanding and to repay borrowings under the Entergy Corporation credit facility, and plans to use the remainder of the proceeds to pay, prior to maturity, its $500 million of 4.7% Series senior notes due January 2017. (Entergy Arkansas) In January 2016, Entergy Arkansas issued $325 million of 3.5% Series first mortgage bonds due April 2026. Entergy Arkansas used the proceeds to pay, prior to maturity, its $175 million of 5.66% Series first mortgage bonds due February 2025, and used the remainder of the proceeds, together with other funds, towards the purchase of Power Block 2 at the Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In June 2016, Entergy Arkansas issued $55 million of 3.5% Series first mortgage bonds due April 2026. These bonds were a further issuance of the 3.5% Series first mortgage bonds issued in January 2016. In July 2016, Entergy Arkansas used the proceeds, together with other funds, to pay, prior to maturity, its $60 million of 6.38% Series first mortgage bonds due November 2034 and for general corporate purposes. In July 2016 the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $55 million of 3.23% Series J notes. In August 2016, Entergy Arkansas issued $410 million of 4.875% Series first mortgage bonds due September 2066. Entergy Arkansas used the proceeds, together with other funds, to redeem $10 million of its 6.08% Series preferred stock, to redeem $75 million of its 6.45% Series preferred stock, to pay, prior to maturity, its $225 million of 5.75% Series first mortgage bonds due November 2040, to pay, prior to maturity, its $100 million of 5.9% Series first mortgage bonds due June 2033, and for general corporate purposes. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. These bonds were a further issuance of the 4.95% Series first mortgage bonds issued in November 2014. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, to repay borrowings under its $350 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana issued $425 million of 3.25% Series collateral trust mortgage bonds due April 2028. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana arranged for the issuance by the Louisiana Public Facilities Authority of (i) $83.680 million of 3.375% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016A due September 2028, and (ii) $115 million of 3.50% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016B due June 2030, each of which series is evidenced by a separate series of non-interest bearing collateral trust mortgage bonds of Entergy Louisiana. The proceeds from these issuances were applied in April 2016 to the refunding of $198.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. In March 2016, Entergy Louisiana issued $51.972 million of Waterford Series collateral trust mortgage notes due July 2017 as part of the purchase of the undivided interests in Waterford 3. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction. In March 2016 the Entergy Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $20 million of 3.30% Series F notes. In May 2016, Entergy Louisiana issued $325 million of 3.05% Series collateral trust mortgage bonds due June 2031. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $240 million of 6.2% Series first mortgage bonds due July 2033 and its $85 million of 6.18% Series first mortgage bonds due March 2035, and for general corporate purposes. In August 2016, Entergy Louisiana issued $270 million of 4.875% Series collateral trust mortgage bonds due September 2066. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $118 million of 6.0% Series first mortgage bonds due March 2040, to pay, prior to maturity, its $150 million of 5.875% Series first mortgage bonds due June 2041, and for general corporate purposes. In October 2016, Entergy Louisiana issued $400 million of 2.40% Series collateral trust mortgage bonds due October 2026. Entergy Louisiana plans to use the proceeds to repay amounts outstanding of approximately $57 million on its Waterford 3 lessor debt due January 2017 and for general corporate purposes. See Note 11 to the financial statements herein for discussion of Entergy Louisiana’s purchase of the undivided interests in Waterford 3. (Entergy Mississippi) In May 2016, Entergy Mississippi issued $375 million of 2.85% Series first mortgage bonds due June 2028. Entergy Mississippi used the proceeds to pay, at maturity, its $125 million of 3.25% Series first mortgage bonds due June 2016, to pay, prior to maturity, its $75 million of 6.0% Series first mortgage bonds due November 2032, and its $100 million of 6.25% Series first mortgage bonds due April 2034, and to cause the repayment of the $30 million of 4.90% pollution control revenue bonds due 2022 issued on behalf of Entergy Mississippi, and for general corporate purposes. In September 2016, Entergy Mississippi issued $260 million of 4.90% Series first mortgage bonds due October 2066. In October 2016, Entergy Mississippi used the proceeds, together with other funds, to pay, prior to maturity, its $80 million of 6.2% Series first mortgage bonds due April 2040, to pay, prior to maturity, its $150 million of 6.0% Series first mortgage bonds due May 2051, and to redeem $30 million of its 6.25% Series preferred stock. (Entergy New Orleans) In March 2016, Entergy New Orleans issued $110 million of 5.50% Series first mortgage bonds due April 2066. Entergy New Orleans used the proceeds to repay borrowings from the money pool, to repay borrowings under its $25 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Block 1 of the Union Power Station. See Note 13 to the financial statements for discussion of the Union Power Station purchase. In May 2016, Entergy New Orleans issued $85 million of 4% Series first mortgage bonds due June 2026. Entergy New Orleans used the proceeds to pay, prior to maturity, its $33.271 million of 5.6% Series first mortgage bonds due September 2024, to pay, prior to maturity, its $37.772 million of 5.65% Series first mortgage bonds due September 2029, and for general corporate purposes. (Entergy Texas) In March 2016, Entergy Texas issued $125 million of 2.55% Series first mortgage bonds due June 2021. Entergy Texas used the proceeds for general corporate purposes. (System Energy) In May 2016, System Energy caused the repayment of $22 million of its $156 million of 5.875% pollution control revenue bonds due 2022 issued on behalf of System Energy. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,611,903 $15,424,412 Entergy Arkansas $2,796,059 $2,791,291 Entergy Louisiana $5,407,897 $5,848,345 Entergy Mississippi $1,344,305 $1,409,719 Entergy New Orleans $459,295 $502,194 Entergy Texas $1,521,270 $1,683,655 System Energy $551,023 $543,933 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 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 and are based on prices derived from inputs such as benchmark yields and reported trades. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2015 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,325,930 $13,578,511 Entergy Arkansas $2,629,839 $2,498,108 Entergy Louisiana $4,836,162 $5,018,786 Entergy Mississippi $1,045,085 $1,087,326 Entergy New Orleans $342,880 $351,040 Entergy Texas $1,451,967 $1,590,616 System Energy $572,667 $552,762 (a) The values exclude lease obligations of $109 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $35 million at Entergy, 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 and are based on prices derived from inputs such as benchmark yields and reported trades.

Stock-Based Compensation

Stock-Based Compensation	9 Months Ended
	Sep. 30, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
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 696,900 shares of its common stock under the 2015 Equity Ownership Plan during the first quarter 2016 with a weighted-average fair value of $7.40 per option. As of September 30, 2016 , there were options on 7,152,077 shares of common stock outstanding with a weighted-average exercise price of $84.93 . 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, 2016 . Because Entergy’s stock price at September 30, 2016 was less than the weighted average exercise price, the aggregate intrinsic value of the stock options outstanding as of September 30, 2016 was zero. The intrinsic value of all “in the money” stock options was $17.7 million as of September 30, 2016 . The following table includes financial information for outstanding stock options for the three months ended September 30, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $1.1 $1.1 Tax benefit recognized in Entergy’s net income $0.5 $0.4 Compensation cost capitalized as part of fixed assets and inventory $0.2 $0.1 The following table includes financial information for outstanding stock options for the nine months ended September 30, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $3.3 $3.2 Tax benefit recognized in Entergy’s net income $1.3 $1.2 Compensation cost capitalized as part of fixed assets and inventory $0.6 $0.5 Other Equity Awards In January 2016 the Board approved and Entergy granted 370,000 restricted stock awards and 199,800 long-term incentive awards under the 2015 Equity Ownership Plan. The restricted stock awards were made effective as of January 28, 2016 and were valued at $70.56 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. The performance units were granted effective as of January 28, 2016 and were valued at $84.52 per share. Entergy considers various factors, primarily market conditions, in determining the value of the performance units. 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, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $8.5 $8.6 Tax benefit recognized in Entergy’s net income $3.3 $3.3 Compensation cost capitalized as part of fixed assets and inventory $2.0 $1.8 The following table includes financial information for other outstanding equity awards for the nine months ended September 30, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $25.4 $24.7 Tax benefit recognized in Entergy’s net income $9.8 $9.5 Compensation cost capitalized as part of fixed assets and inventory $5.7 $4.9

Retirement And Other Postretire

Retirement And Other Postretirement Benefits	9 Months Ended
	Sep. 30, 2016
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $107,433 $131,286 Interest cost on projected benefit obligation 196,209 227,082 Expected return on assets (292,098 ) (295,965 ) Amortization of prior service cost 810 1,170 Amortization of loss 146,472 176,943 Special termination benefit — 76 Net pension costs $158,826 $240,592 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,543 $21,147 $4,686 $1,968 $4,248 $4,698 Interest cost on projected benefit obligation 39,165 44,610 11,433 5,442 10,671 8,976 Expected return on assets (59,316 ) (66,288 ) (17,943 ) (8,061 ) (18,186 ) (13,377 ) Amortization of loss 32,808 35,838 8,955 4,845 7,020 7,812 Net pension cost $28,200 $35,307 $7,131 $4,194 $3,753 $8,109 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $19,983 $25,797 $5,946 $2,547 $4,935 $5,871 Interest cost on projected benefit obligation 46,413 52,101 13,506 6,324 13,062 10,479 Expected return on assets (60,078 ) (68,103 ) (18,315 ) (8,175 ) (18,666 ) (13,704 ) Amortization of loss 40,692 44,853 11,172 6,039 9,714 9,792 Net pension cost $47,010 $54,648 $12,309 $6,735 $9,045 $12,438 Non-Qualified Net Pension Cost Entergy recognized $8 million and $4.5 million in pension cost for its non-qualified pension plans in the third quarters of 2016 and 2015 , respectively. Entergy recognized $16.5 million and $13.4 million in pension costs for its non-qualified pension plans for the nine months ended September 30, 2016 and 2015, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarter of 2016 and for the nine months ended September 30, 2016 is a $3.7 million settlement charge 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 in the third quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Third quarter 2016 $105 $58 $60 $16 $126 Third quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Nine months ended September 30, 2016 $317 $176 $179 $48 $380 Nine months ended September 30, 2015 $339 $204 $177 $48 $447 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the third quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $24,219 $33,978 Interest cost on accumulated postretirement benefit obligation (APBO) 42,249 53,952 Expected return on assets (31,365 ) (34,032 ) Amortization of prior service credit (34,119 ) (27,960 ) Amortization of loss 13,662 23,679 Net other postretirement benefit cost $14,646 $49,617 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the third quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,934 $5,607 $1,158 $468 $1,194 $1,002 Interest cost on APBO 6,972 9,780 2,127 1,344 3,117 1,587 Expected return on assets (13,392 ) — (4,137 ) (3,462 ) (7,182 ) (2,442 ) Amortization of prior service credit (4,104 ) (5,841 ) (702 ) (558 ) (2,043 ) (1,179 ) Amortization of loss 3,192 2,196 669 111 1,611 861 Net other postretirement benefit cost ($4,398 ) $11,742 ($885 ) ($2,097 ) ($3,303 ) ($171 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,217 $7,422 $1,521 $615 $1,500 $1,410 Interest cost on APBO 9,390 12,234 2,577 1,956 4,026 1,884 Expected return on assets (14,394 ) — (4,626 ) (3,603 ) (7,764 ) (2,733 ) Amortization of prior service credit (1,830 ) (5,601 ) (687 ) (531 ) (2,043 ) (1,098 ) Amortization of loss 4,017 5,340 645 354 2,055 900 Net other postretirement benefit cost $2,400 $19,395 ($570 ) ($1,209 ) ($2,226 ) $363 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 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($114 ) $7,354 Amortization of loss (12,482 ) (2,063 ) (638 ) (15,183 ) Settlement loss — — (1,279 ) (1,279 ) ($12,752 ) $5,675 ($2,031 ) ($9,108 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (2 ) (1,570 ) ($836 ) $1,215 ($2 ) $377 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,780 ) (5 ) (2,536 ) ($751 ) $87 ($6 ) ($670 ) 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, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($810 ) $23,214 ($340 ) $22,064 Amortization of loss (37,446 ) (6,189 ) (1,900 ) (45,535 ) Settlement loss — — (1,279 ) (1,279 ) ($38,256 ) $17,025 ($3,519 ) ($24,750 ) Entergy Louisiana Amortization of prior service credit $— $5,841 $— $5,841 Amortization of loss (2,508 ) (2,196 ) (8 ) (4,712 ) ($2,508 ) $3,645 ($8 ) $1,129 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($1,167 ) $19,446 ($323 ) $17,956 Amortization of loss (37,881 ) (13,227 ) (1,656 ) (52,764 ) ($39,048 ) $6,219 ($1,979 ) ($34,808 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $5,601 ($2 ) $5,599 Amortization of loss (2,253 ) (5,338 ) (15 ) (7,606 ) ($2,253 ) $263 ($17 ) ($2,007 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $390.1 million to its qualified pension plans in 2016. As of September 30, 2016 , Entergy had contributed $307.6 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 2016 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2016 pension contributions $83,001 $84,422 $19,968 $10,709 $15,920 $20,498 Pension contributions made through September 2016 $65,882 $67,116 $15,981 $8,456 $12,649 $16,120 Remaining estimated pension contributions to be made in 2016 $17,119 $17,306 $3,987 $2,253 $3,271 $4,378
Entergy Arkansas [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $107,433 $131,286 Interest cost on projected benefit obligation 196,209 227,082 Expected return on assets (292,098 ) (295,965 ) Amortization of prior service cost 810 1,170 Amortization of loss 146,472 176,943 Special termination benefit — 76 Net pension costs $158,826 $240,592 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,543 $21,147 $4,686 $1,968 $4,248 $4,698 Interest cost on projected benefit obligation 39,165 44,610 11,433 5,442 10,671 8,976 Expected return on assets (59,316 ) (66,288 ) (17,943 ) (8,061 ) (18,186 ) (13,377 ) Amortization of loss 32,808 35,838 8,955 4,845 7,020 7,812 Net pension cost $28,200 $35,307 $7,131 $4,194 $3,753 $8,109 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $19,983 $25,797 $5,946 $2,547 $4,935 $5,871 Interest cost on projected benefit obligation 46,413 52,101 13,506 6,324 13,062 10,479 Expected return on assets (60,078 ) (68,103 ) (18,315 ) (8,175 ) (18,666 ) (13,704 ) Amortization of loss 40,692 44,853 11,172 6,039 9,714 9,792 Net pension cost $47,010 $54,648 $12,309 $6,735 $9,045 $12,438 Non-Qualified Net Pension Cost Entergy recognized $8 million and $4.5 million in pension cost for its non-qualified pension plans in the third quarters of 2016 and 2015 , respectively. Entergy recognized $16.5 million and $13.4 million in pension costs for its non-qualified pension plans for the nine months ended September 30, 2016 and 2015, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarter of 2016 and for the nine months ended September 30, 2016 is a $3.7 million settlement charge 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 in the third quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Third quarter 2016 $105 $58 $60 $16 $126 Third quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Nine months ended September 30, 2016 $317 $176 $179 $48 $380 Nine months ended September 30, 2015 $339 $204 $177 $48 $447 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the third quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $24,219 $33,978 Interest cost on accumulated postretirement benefit obligation (APBO) 42,249 53,952 Expected return on assets (31,365 ) (34,032 ) Amortization of prior service credit (34,119 ) (27,960 ) Amortization of loss 13,662 23,679 Net other postretirement benefit cost $14,646 $49,617 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the third quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,934 $5,607 $1,158 $468 $1,194 $1,002 Interest cost on APBO 6,972 9,780 2,127 1,344 3,117 1,587 Expected return on assets (13,392 ) — (4,137 ) (3,462 ) (7,182 ) (2,442 ) Amortization of prior service credit (4,104 ) (5,841 ) (702 ) (558 ) (2,043 ) (1,179 ) Amortization of loss 3,192 2,196 669 111 1,611 861 Net other postretirement benefit cost ($4,398 ) $11,742 ($885 ) ($2,097 ) ($3,303 ) ($171 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,217 $7,422 $1,521 $615 $1,500 $1,410 Interest cost on APBO 9,390 12,234 2,577 1,956 4,026 1,884 Expected return on assets (14,394 ) — (4,626 ) (3,603 ) (7,764 ) (2,733 ) Amortization of prior service credit (1,830 ) (5,601 ) (687 ) (531 ) (2,043 ) (1,098 ) Amortization of loss 4,017 5,340 645 354 2,055 900 Net other postretirement benefit cost $2,400 $19,395 ($570 ) ($1,209 ) ($2,226 ) $363 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 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($114 ) $7,354 Amortization of loss (12,482 ) (2,063 ) (638 ) (15,183 ) Settlement loss — — (1,279 ) (1,279 ) ($12,752 ) $5,675 ($2,031 ) ($9,108 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (2 ) (1,570 ) ($836 ) $1,215 ($2 ) $377 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,780 ) (5 ) (2,536 ) ($751 ) $87 ($6 ) ($670 ) 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, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($810 ) $23,214 ($340 ) $22,064 Amortization of loss (37,446 ) (6,189 ) (1,900 ) (45,535 ) Settlement loss — — (1,279 ) (1,279 ) ($38,256 ) $17,025 ($3,519 ) ($24,750 ) Entergy Louisiana Amortization of prior service credit $— $5,841 $— $5,841 Amortization of loss (2,508 ) (2,196 ) (8 ) (4,712 ) ($2,508 ) $3,645 ($8 ) $1,129 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($1,167 ) $19,446 ($323 ) $17,956 Amortization of loss (37,881 ) (13,227 ) (1,656 ) (52,764 ) ($39,048 ) $6,219 ($1,979 ) ($34,808 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $5,601 ($2 ) $5,599 Amortization of loss (2,253 ) (5,338 ) (15 ) (7,606 ) ($2,253 ) $263 ($17 ) ($2,007 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $390.1 million to its qualified pension plans in 2016. As of September 30, 2016 , Entergy had contributed $307.6 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 2016 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2016 pension contributions $83,001 $84,422 $19,968 $10,709 $15,920 $20,498 Pension contributions made through September 2016 $65,882 $67,116 $15,981 $8,456 $12,649 $16,120 Remaining estimated pension contributions to be made in 2016 $17,119 $17,306 $3,987 $2,253 $3,271 $4,378
Entergy Louisiana [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $107,433 $131,286 Interest cost on projected benefit obligation 196,209 227,082 Expected return on assets (292,098 ) (295,965 ) Amortization of prior service cost 810 1,170 Amortization of loss 146,472 176,943 Special termination benefit — 76 Net pension costs $158,826 $240,592 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,543 $21,147 $4,686 $1,968 $4,248 $4,698 Interest cost on projected benefit obligation 39,165 44,610 11,433 5,442 10,671 8,976 Expected return on assets (59,316 ) (66,288 ) (17,943 ) (8,061 ) (18,186 ) (13,377 ) Amortization of loss 32,808 35,838 8,955 4,845 7,020 7,812 Net pension cost $28,200 $35,307 $7,131 $4,194 $3,753 $8,109 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $19,983 $25,797 $5,946 $2,547 $4,935 $5,871 Interest cost on projected benefit obligation 46,413 52,101 13,506 6,324 13,062 10,479 Expected return on assets (60,078 ) (68,103 ) (18,315 ) (8,175 ) (18,666 ) (13,704 ) Amortization of loss 40,692 44,853 11,172 6,039 9,714 9,792 Net pension cost $47,010 $54,648 $12,309 $6,735 $9,045 $12,438 Non-Qualified Net Pension Cost Entergy recognized $8 million and $4.5 million in pension cost for its non-qualified pension plans in the third quarters of 2016 and 2015 , respectively. Entergy recognized $16.5 million and $13.4 million in pension costs for its non-qualified pension plans for the nine months ended September 30, 2016 and 2015, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarter of 2016 and for the nine months ended September 30, 2016 is a $3.7 million settlement charge 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 in the third quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Third quarter 2016 $105 $58 $60 $16 $126 Third quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Nine months ended September 30, 2016 $317 $176 $179 $48 $380 Nine months ended September 30, 2015 $339 $204 $177 $48 $447 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the third quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $24,219 $33,978 Interest cost on accumulated postretirement benefit obligation (APBO) 42,249 53,952 Expected return on assets (31,365 ) (34,032 ) Amortization of prior service credit (34,119 ) (27,960 ) Amortization of loss 13,662 23,679 Net other postretirement benefit cost $14,646 $49,617 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the third quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,934 $5,607 $1,158 $468 $1,194 $1,002 Interest cost on APBO 6,972 9,780 2,127 1,344 3,117 1,587 Expected return on assets (13,392 ) — (4,137 ) (3,462 ) (7,182 ) (2,442 ) Amortization of prior service credit (4,104 ) (5,841 ) (702 ) (558 ) (2,043 ) (1,179 ) Amortization of loss 3,192 2,196 669 111 1,611 861 Net other postretirement benefit cost ($4,398 ) $11,742 ($885 ) ($2,097 ) ($3,303 ) ($171 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,217 $7,422 $1,521 $615 $1,500 $1,410 Interest cost on APBO 9,390 12,234 2,577 1,956 4,026 1,884 Expected return on assets (14,394 ) — (4,626 ) (3,603 ) (7,764 ) (2,733 ) Amortization of prior service credit (1,830 ) (5,601 ) (687 ) (531 ) (2,043 ) (1,098 ) Amortization of loss 4,017 5,340 645 354 2,055 900 Net other postretirement benefit cost $2,400 $19,395 ($570 ) ($1,209 ) ($2,226 ) $363 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 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($114 ) $7,354 Amortization of loss (12,482 ) (2,063 ) (638 ) (15,183 ) Settlement loss — — (1,279 ) (1,279 ) ($12,752 ) $5,675 ($2,031 ) ($9,108 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (2 ) (1,570 ) ($836 ) $1,215 ($2 ) $377 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,780 ) (5 ) (2,536 ) ($751 ) $87 ($6 ) ($670 ) 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, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($810 ) $23,214 ($340 ) $22,064 Amortization of loss (37,446 ) (6,189 ) (1,900 ) (45,535 ) Settlement loss — — (1,279 ) (1,279 ) ($38,256 ) $17,025 ($3,519 ) ($24,750 ) Entergy Louisiana Amortization of prior service credit $— $5,841 $— $5,841 Amortization of loss (2,508 ) (2,196 ) (8 ) (4,712 ) ($2,508 ) $3,645 ($8 ) $1,129 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($1,167 ) $19,446 ($323 ) $17,956 Amortization of loss (37,881 ) (13,227 ) (1,656 ) (52,764 ) ($39,048 ) $6,219 ($1,979 ) ($34,808 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $5,601 ($2 ) $5,599 Amortization of loss (2,253 ) (5,338 ) (15 ) (7,606 ) ($2,253 ) $263 ($17 ) ($2,007 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $390.1 million to its qualified pension plans in 2016. As of September 30, 2016 , Entergy had contributed $307.6 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 2016 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2016 pension contributions $83,001 $84,422 $19,968 $10,709 $15,920 $20,498 Pension contributions made through September 2016 $65,882 $67,116 $15,981 $8,456 $12,649 $16,120 Remaining estimated pension contributions to be made in 2016 $17,119 $17,306 $3,987 $2,253 $3,271 $4,378
Entergy Mississippi [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $107,433 $131,286 Interest cost on projected benefit obligation 196,209 227,082 Expected return on assets (292,098 ) (295,965 ) Amortization of prior service cost 810 1,170 Amortization of loss 146,472 176,943 Special termination benefit — 76 Net pension costs $158,826 $240,592 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,543 $21,147 $4,686 $1,968 $4,248 $4,698 Interest cost on projected benefit obligation 39,165 44,610 11,433 5,442 10,671 8,976 Expected return on assets (59,316 ) (66,288 ) (17,943 ) (8,061 ) (18,186 ) (13,377 ) Amortization of loss 32,808 35,838 8,955 4,845 7,020 7,812 Net pension cost $28,200 $35,307 $7,131 $4,194 $3,753 $8,109 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $19,983 $25,797 $5,946 $2,547 $4,935 $5,871 Interest cost on projected benefit obligation 46,413 52,101 13,506 6,324 13,062 10,479 Expected return on assets (60,078 ) (68,103 ) (18,315 ) (8,175 ) (18,666 ) (13,704 ) Amortization of loss 40,692 44,853 11,172 6,039 9,714 9,792 Net pension cost $47,010 $54,648 $12,309 $6,735 $9,045 $12,438 Non-Qualified Net Pension Cost Entergy recognized $8 million and $4.5 million in pension cost for its non-qualified pension plans in the third quarters of 2016 and 2015 , respectively. Entergy recognized $16.5 million and $13.4 million in pension costs for its non-qualified pension plans for the nine months ended September 30, 2016 and 2015, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarter of 2016 and for the nine months ended September 30, 2016 is a $3.7 million settlement charge 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 in the third quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Third quarter 2016 $105 $58 $60 $16 $126 Third quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Nine months ended September 30, 2016 $317 $176 $179 $48 $380 Nine months ended September 30, 2015 $339 $204 $177 $48 $447 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the third quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $24,219 $33,978 Interest cost on accumulated postretirement benefit obligation (APBO) 42,249 53,952 Expected return on assets (31,365 ) (34,032 ) Amortization of prior service credit (34,119 ) (27,960 ) Amortization of loss 13,662 23,679 Net other postretirement benefit cost $14,646 $49,617 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the third quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,934 $5,607 $1,158 $468 $1,194 $1,002 Interest cost on APBO 6,972 9,780 2,127 1,344 3,117 1,587 Expected return on assets (13,392 ) — (4,137 ) (3,462 ) (7,182 ) (2,442 ) Amortization of prior service credit (4,104 ) (5,841 ) (702 ) (558 ) (2,043 ) (1,179 ) Amortization of loss 3,192 2,196 669 111 1,611 861 Net other postretirement benefit cost ($4,398 ) $11,742 ($885 ) ($2,097 ) ($3,303 ) ($171 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,217 $7,422 $1,521 $615 $1,500 $1,410 Interest cost on APBO 9,390 12,234 2,577 1,956 4,026 1,884 Expected return on assets (14,394 ) — (4,626 ) (3,603 ) (7,764 ) (2,733 ) Amortization of prior service credit (1,830 ) (5,601 ) (687 ) (531 ) (2,043 ) (1,098 ) Amortization of loss 4,017 5,340 645 354 2,055 900 Net other postretirement benefit cost $2,400 $19,395 ($570 ) ($1,209 ) ($2,226 ) $363 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 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($114 ) $7,354 Amortization of loss (12,482 ) (2,063 ) (638 ) (15,183 ) Settlement loss — — (1,279 ) (1,279 ) ($12,752 ) $5,675 ($2,031 ) ($9,108 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (2 ) (1,570 ) ($836 ) $1,215 ($2 ) $377 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,780 ) (5 ) (2,536 ) ($751 ) $87 ($6 ) ($670 ) 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, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($810 ) $23,214 ($340 ) $22,064 Amortization of loss (37,446 ) (6,189 ) (1,900 ) (45,535 ) Settlement loss — — (1,279 ) (1,279 ) ($38,256 ) $17,025 ($3,519 ) ($24,750 ) Entergy Louisiana Amortization of prior service credit $— $5,841 $— $5,841 Amortization of loss (2,508 ) (2,196 ) (8 ) (4,712 ) ($2,508 ) $3,645 ($8 ) $1,129 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($1,167 ) $19,446 ($323 ) $17,956 Amortization of loss (37,881 ) (13,227 ) (1,656 ) (52,764 ) ($39,048 ) $6,219 ($1,979 ) ($34,808 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $5,601 ($2 ) $5,599 Amortization of loss (2,253 ) (5,338 ) (15 ) (7,606 ) ($2,253 ) $263 ($17 ) ($2,007 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $390.1 million to its qualified pension plans in 2016. As of September 30, 2016 , Entergy had contributed $307.6 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 2016 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2016 pension contributions $83,001 $84,422 $19,968 $10,709 $15,920 $20,498 Pension contributions made through September 2016 $65,882 $67,116 $15,981 $8,456 $12,649 $16,120 Remaining estimated pension contributions to be made in 2016 $17,119 $17,306 $3,987 $2,253 $3,271 $4,378
Entergy New Orleans [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $107,433 $131,286 Interest cost on projected benefit obligation 196,209 227,082 Expected return on assets (292,098 ) (295,965 ) Amortization of prior service cost 810 1,170 Amortization of loss 146,472 176,943 Special termination benefit — 76 Net pension costs $158,826 $240,592 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,543 $21,147 $4,686 $1,968 $4,248 $4,698 Interest cost on projected benefit obligation 39,165 44,610 11,433 5,442 10,671 8,976 Expected return on assets (59,316 ) (66,288 ) (17,943 ) (8,061 ) (18,186 ) (13,377 ) Amortization of loss 32,808 35,838 8,955 4,845 7,020 7,812 Net pension cost $28,200 $35,307 $7,131 $4,194 $3,753 $8,109 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $19,983 $25,797 $5,946 $2,547 $4,935 $5,871 Interest cost on projected benefit obligation 46,413 52,101 13,506 6,324 13,062 10,479 Expected return on assets (60,078 ) (68,103 ) (18,315 ) (8,175 ) (18,666 ) (13,704 ) Amortization of loss 40,692 44,853 11,172 6,039 9,714 9,792 Net pension cost $47,010 $54,648 $12,309 $6,735 $9,045 $12,438 Non-Qualified Net Pension Cost Entergy recognized $8 million and $4.5 million in pension cost for its non-qualified pension plans in the third quarters of 2016 and 2015 , respectively. Entergy recognized $16.5 million and $13.4 million in pension costs for its non-qualified pension plans for the nine months ended September 30, 2016 and 2015, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarter of 2016 and for the nine months ended September 30, 2016 is a $3.7 million settlement charge 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 in the third quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Third quarter 2016 $105 $58 $60 $16 $126 Third quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Nine months ended September 30, 2016 $317 $176 $179 $48 $380 Nine months ended September 30, 2015 $339 $204 $177 $48 $447 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the third quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $24,219 $33,978 Interest cost on accumulated postretirement benefit obligation (APBO) 42,249 53,952 Expected return on assets (31,365 ) (34,032 ) Amortization of prior service credit (34,119 ) (27,960 ) Amortization of loss 13,662 23,679 Net other postretirement benefit cost $14,646 $49,617 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the third quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,934 $5,607 $1,158 $468 $1,194 $1,002 Interest cost on APBO 6,972 9,780 2,127 1,344 3,117 1,587 Expected return on assets (13,392 ) — (4,137 ) (3,462 ) (7,182 ) (2,442 ) Amortization of prior service credit (4,104 ) (5,841 ) (702 ) (558 ) (2,043 ) (1,179 ) Amortization of loss 3,192 2,196 669 111 1,611 861 Net other postretirement benefit cost ($4,398 ) $11,742 ($885 ) ($2,097 ) ($3,303 ) ($171 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,217 $7,422 $1,521 $615 $1,500 $1,410 Interest cost on APBO 9,390 12,234 2,577 1,956 4,026 1,884 Expected return on assets (14,394 ) — (4,626 ) (3,603 ) (7,764 ) (2,733 ) Amortization of prior service credit (1,830 ) (5,601 ) (687 ) (531 ) (2,043 ) (1,098 ) Amortization of loss 4,017 5,340 645 354 2,055 900 Net other postretirement benefit cost $2,400 $19,395 ($570 ) ($1,209 ) ($2,226 ) $363 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 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($114 ) $7,354 Amortization of loss (12,482 ) (2,063 ) (638 ) (15,183 ) Settlement loss — — (1,279 ) (1,279 ) ($12,752 ) $5,675 ($2,031 ) ($9,108 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (2 ) (1,570 ) ($836 ) $1,215 ($2 ) $377 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,780 ) (5 ) (2,536 ) ($751 ) $87 ($6 ) ($670 ) 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, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($810 ) $23,214 ($340 ) $22,064 Amortization of loss (37,446 ) (6,189 ) (1,900 ) (45,535 ) Settlement loss — — (1,279 ) (1,279 ) ($38,256 ) $17,025 ($3,519 ) ($24,750 ) Entergy Louisiana Amortization of prior service credit $— $5,841 $— $5,841 Amortization of loss (2,508 ) (2,196 ) (8 ) (4,712 ) ($2,508 ) $3,645 ($8 ) $1,129 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($1,167 ) $19,446 ($323 ) $17,956 Amortization of loss (37,881 ) (13,227 ) (1,656 ) (52,764 ) ($39,048 ) $6,219 ($1,979 ) ($34,808 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $5,601 ($2 ) $5,599 Amortization of loss (2,253 ) (5,338 ) (15 ) (7,606 ) ($2,253 ) $263 ($17 ) ($2,007 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $390.1 million to its qualified pension plans in 2016. As of September 30, 2016 , Entergy had contributed $307.6 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 2016 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2016 pension contributions $83,001 $84,422 $19,968 $10,709 $15,920 $20,498 Pension contributions made through September 2016 $65,882 $67,116 $15,981 $8,456 $12,649 $16,120 Remaining estimated pension contributions to be made in 2016 $17,119 $17,306 $3,987 $2,253 $3,271 $4,378
Entergy Texas [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $107,433 $131,286 Interest cost on projected benefit obligation 196,209 227,082 Expected return on assets (292,098 ) (295,965 ) Amortization of prior service cost 810 1,170 Amortization of loss 146,472 176,943 Special termination benefit — 76 Net pension costs $158,826 $240,592 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,543 $21,147 $4,686 $1,968 $4,248 $4,698 Interest cost on projected benefit obligation 39,165 44,610 11,433 5,442 10,671 8,976 Expected return on assets (59,316 ) (66,288 ) (17,943 ) (8,061 ) (18,186 ) (13,377 ) Amortization of loss 32,808 35,838 8,955 4,845 7,020 7,812 Net pension cost $28,200 $35,307 $7,131 $4,194 $3,753 $8,109 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $19,983 $25,797 $5,946 $2,547 $4,935 $5,871 Interest cost on projected benefit obligation 46,413 52,101 13,506 6,324 13,062 10,479 Expected return on assets (60,078 ) (68,103 ) (18,315 ) (8,175 ) (18,666 ) (13,704 ) Amortization of loss 40,692 44,853 11,172 6,039 9,714 9,792 Net pension cost $47,010 $54,648 $12,309 $6,735 $9,045 $12,438 Non-Qualified Net Pension Cost Entergy recognized $8 million and $4.5 million in pension cost for its non-qualified pension plans in the third quarters of 2016 and 2015 , respectively. Entergy recognized $16.5 million and $13.4 million in pension costs for its non-qualified pension plans for the nine months ended September 30, 2016 and 2015, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarter of 2016 and for the nine months ended September 30, 2016 is a $3.7 million settlement charge 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 in the third quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Third quarter 2016 $105 $58 $60 $16 $126 Third quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Nine months ended September 30, 2016 $317 $176 $179 $48 $380 Nine months ended September 30, 2015 $339 $204 $177 $48 $447 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the third quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $24,219 $33,978 Interest cost on accumulated postretirement benefit obligation (APBO) 42,249 53,952 Expected return on assets (31,365 ) (34,032 ) Amortization of prior service credit (34,119 ) (27,960 ) Amortization of loss 13,662 23,679 Net other postretirement benefit cost $14,646 $49,617 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the third quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,934 $5,607 $1,158 $468 $1,194 $1,002 Interest cost on APBO 6,972 9,780 2,127 1,344 3,117 1,587 Expected return on assets (13,392 ) — (4,137 ) (3,462 ) (7,182 ) (2,442 ) Amortization of prior service credit (4,104 ) (5,841 ) (702 ) (558 ) (2,043 ) (1,179 ) Amortization of loss 3,192 2,196 669 111 1,611 861 Net other postretirement benefit cost ($4,398 ) $11,742 ($885 ) ($2,097 ) ($3,303 ) ($171 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,217 $7,422 $1,521 $615 $1,500 $1,410 Interest cost on APBO 9,390 12,234 2,577 1,956 4,026 1,884 Expected return on assets (14,394 ) — (4,626 ) (3,603 ) (7,764 ) (2,733 ) Amortization of prior service credit (1,830 ) (5,601 ) (687 ) (531 ) (2,043 ) (1,098 ) Amortization of loss 4,017 5,340 645 354 2,055 900 Net other postretirement benefit cost $2,400 $19,395 ($570 ) ($1,209 ) ($2,226 ) $363 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 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($114 ) $7,354 Amortization of loss (12,482 ) (2,063 ) (638 ) (15,183 ) Settlement loss — — (1,279 ) (1,279 ) ($12,752 ) $5,675 ($2,031 ) ($9,108 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (2 ) (1,570 ) ($836 ) $1,215 ($2 ) $377 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,780 ) (5 ) (2,536 ) ($751 ) $87 ($6 ) ($670 ) 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, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($810 ) $23,214 ($340 ) $22,064 Amortization of loss (37,446 ) (6,189 ) (1,900 ) (45,535 ) Settlement loss — — (1,279 ) (1,279 ) ($38,256 ) $17,025 ($3,519 ) ($24,750 ) Entergy Louisiana Amortization of prior service credit $— $5,841 $— $5,841 Amortization of loss (2,508 ) (2,196 ) (8 ) (4,712 ) ($2,508 ) $3,645 ($8 ) $1,129 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($1,167 ) $19,446 ($323 ) $17,956 Amortization of loss (37,881 ) (13,227 ) (1,656 ) (52,764 ) ($39,048 ) $6,219 ($1,979 ) ($34,808 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $5,601 ($2 ) $5,599 Amortization of loss (2,253 ) (5,338 ) (15 ) (7,606 ) ($2,253 ) $263 ($17 ) ($2,007 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $390.1 million to its qualified pension plans in 2016. As of September 30, 2016 , Entergy had contributed $307.6 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 2016 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2016 pension contributions $83,001 $84,422 $19,968 $10,709 $15,920 $20,498 Pension contributions made through September 2016 $65,882 $67,116 $15,981 $8,456 $12,649 $16,120 Remaining estimated pension contributions to be made in 2016 $17,119 $17,306 $3,987 $2,253 $3,271 $4,378
System Energy [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $107,433 $131,286 Interest cost on projected benefit obligation 196,209 227,082 Expected return on assets (292,098 ) (295,965 ) Amortization of prior service cost 810 1,170 Amortization of loss 146,472 176,943 Special termination benefit — 76 Net pension costs $158,826 $240,592 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,543 $21,147 $4,686 $1,968 $4,248 $4,698 Interest cost on projected benefit obligation 39,165 44,610 11,433 5,442 10,671 8,976 Expected return on assets (59,316 ) (66,288 ) (17,943 ) (8,061 ) (18,186 ) (13,377 ) Amortization of loss 32,808 35,838 8,955 4,845 7,020 7,812 Net pension cost $28,200 $35,307 $7,131 $4,194 $3,753 $8,109 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $19,983 $25,797 $5,946 $2,547 $4,935 $5,871 Interest cost on projected benefit obligation 46,413 52,101 13,506 6,324 13,062 10,479 Expected return on assets (60,078 ) (68,103 ) (18,315 ) (8,175 ) (18,666 ) (13,704 ) Amortization of loss 40,692 44,853 11,172 6,039 9,714 9,792 Net pension cost $47,010 $54,648 $12,309 $6,735 $9,045 $12,438 Non-Qualified Net Pension Cost Entergy recognized $8 million and $4.5 million in pension cost for its non-qualified pension plans in the third quarters of 2016 and 2015 , respectively. Entergy recognized $16.5 million and $13.4 million in pension costs for its non-qualified pension plans for the nine months ended September 30, 2016 and 2015, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarter of 2016 and for the nine months ended September 30, 2016 is a $3.7 million settlement charge 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 in the third quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Third quarter 2016 $105 $58 $60 $16 $126 Third quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Nine months ended September 30, 2016 $317 $176 $179 $48 $380 Nine months ended September 30, 2015 $339 $204 $177 $48 $447 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the third quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $24,219 $33,978 Interest cost on accumulated postretirement benefit obligation (APBO) 42,249 53,952 Expected return on assets (31,365 ) (34,032 ) Amortization of prior service credit (34,119 ) (27,960 ) Amortization of loss 13,662 23,679 Net other postretirement benefit cost $14,646 $49,617 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the third quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,934 $5,607 $1,158 $468 $1,194 $1,002 Interest cost on APBO 6,972 9,780 2,127 1,344 3,117 1,587 Expected return on assets (13,392 ) — (4,137 ) (3,462 ) (7,182 ) (2,442 ) Amortization of prior service credit (4,104 ) (5,841 ) (702 ) (558 ) (2,043 ) (1,179 ) Amortization of loss 3,192 2,196 669 111 1,611 861 Net other postretirement benefit cost ($4,398 ) $11,742 ($885 ) ($2,097 ) ($3,303 ) ($171 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,217 $7,422 $1,521 $615 $1,500 $1,410 Interest cost on APBO 9,390 12,234 2,577 1,956 4,026 1,884 Expected return on assets (14,394 ) — (4,626 ) (3,603 ) (7,764 ) (2,733 ) Amortization of prior service credit (1,830 ) (5,601 ) (687 ) (531 ) (2,043 ) (1,098 ) Amortization of loss 4,017 5,340 645 354 2,055 900 Net other postretirement benefit cost $2,400 $19,395 ($570 ) ($1,209 ) ($2,226 ) $363 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 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($114 ) $7,354 Amortization of loss (12,482 ) (2,063 ) (638 ) (15,183 ) Settlement loss — — (1,279 ) (1,279 ) ($12,752 ) $5,675 ($2,031 ) ($9,108 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (2 ) (1,570 ) ($836 ) $1,215 ($2 ) $377 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,780 ) (5 ) (2,536 ) ($751 ) $87 ($6 ) ($670 ) 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, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($810 ) $23,214 ($340 ) $22,064 Amortization of loss (37,446 ) (6,189 ) (1,900 ) (45,535 ) Settlement loss — — (1,279 ) (1,279 ) ($38,256 ) $17,025 ($3,519 ) ($24,750 ) Entergy Louisiana Amortization of prior service credit $— $5,841 $— $5,841 Amortization of loss (2,508 ) (2,196 ) (8 ) (4,712 ) ($2,508 ) $3,645 ($8 ) $1,129 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($1,167 ) $19,446 ($323 ) $17,956 Amortization of loss (37,881 ) (13,227 ) (1,656 ) (52,764 ) ($39,048 ) $6,219 ($1,979 ) ($34,808 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $5,601 ($2 ) $5,599 Amortization of loss (2,253 ) (5,338 ) (15 ) (7,606 ) ($2,253 ) $263 ($17 ) ($2,007 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $390.1 million to its qualified pension plans in 2016. As of September 30, 2016 , Entergy had contributed $307.6 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 2016 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2016 pension contributions $83,001 $84,422 $19,968 $10,709 $15,920 $20,498 Pension contributions made through September 2016 $65,882 $67,116 $15,981 $8,456 $12,649 $16,120 Remaining estimated pension contributions to be made in 2016 $17,119 $17,306 $3,987 $2,253 $3,271 $4,378

Business Segment Information

Business Segment Information	9 Months Ended
	Sep. 30, 2016
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, 2016 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,649,392 $475,345 $— ($34 ) $3,124,703 Income taxes $255,603 $6,115 ($3,812 ) $— $257,906 Consolidated net income (loss) $447,782 $8,221 ($30,901 ) ($31,898 ) $393,204 2015 Operating revenues $2,849,681 $521,746 $— ($21 ) $3,371,406 Income taxes $198,945 ($554,513 ) ($12,097 ) $— ($367,665 ) Consolidated net income (loss) $364,265 ($1,031,410 ) ($19,190 ) ($31,898 ) ($718,233 ) Entergy’s segment financial information for the nine months ended September 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $6,855,664 $1,341,534 $— ($80 ) $8,197,118 Income taxes $359,653 ($176,626 ) ($34,148 ) $— $148,879 Consolidated net income (loss) $1,027,751 $338,651 ($69,672 ) ($95,695 ) $1,201,035 Total assets as of September 30, 2016 $40,542,593 $9,100,779 $1,339,879 ($3,245,070 ) $47,738,181 2015 Operating revenues $7,401,136 $1,603,643 $— ($51 ) $9,004,728 Income taxes $407,993 ($487,622 ) ($37,783 ) $— ($117,412 ) Consolidated net income (loss) $796,051 ($911,524 ) ($50,415 ) ($95,695 ) ($261,583 ) Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. 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, 2016 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,649,392 $475,345 $— ($34 ) $3,124,703 Income taxes $255,603 $6,115 ($3,812 ) $— $257,906 Consolidated net income (loss) $447,782 $8,221 ($30,901 ) ($31,898 ) $393,204 2015 Operating revenues $2,849,681 $521,746 $— ($21 ) $3,371,406 Income taxes $198,945 ($554,513 ) ($12,097 ) $— ($367,665 ) Consolidated net income (loss) $364,265 ($1,031,410 ) ($19,190 ) ($31,898 ) ($718,233 ) Entergy’s segment financial information for the nine months ended September 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $6,855,664 $1,341,534 $— ($80 ) $8,197,118 Income taxes $359,653 ($176,626 ) ($34,148 ) $— $148,879 Consolidated net income (loss) $1,027,751 $338,651 ($69,672 ) ($95,695 ) $1,201,035 Total assets as of September 30, 2016 $40,542,593 $9,100,779 $1,339,879 ($3,245,070 ) $47,738,181 2015 Operating revenues $7,401,136 $1,603,643 $— ($51 ) $9,004,728 Income taxes $407,993 ($487,622 ) ($37,783 ) $— ($117,412 ) Consolidated net income (loss) $796,051 ($911,524 ) ($50,415 ) ($95,695 ) ($261,583 ) Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. 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, 2016 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,649,392 $475,345 $— ($34 ) $3,124,703 Income taxes $255,603 $6,115 ($3,812 ) $— $257,906 Consolidated net income (loss) $447,782 $8,221 ($30,901 ) ($31,898 ) $393,204 2015 Operating revenues $2,849,681 $521,746 $— ($21 ) $3,371,406 Income taxes $198,945 ($554,513 ) ($12,097 ) $— ($367,665 ) Consolidated net income (loss) $364,265 ($1,031,410 ) ($19,190 ) ($31,898 ) ($718,233 ) Entergy’s segment financial information for the nine months ended September 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $6,855,664 $1,341,534 $— ($80 ) $8,197,118 Income taxes $359,653 ($176,626 ) ($34,148 ) $— $148,879 Consolidated net income (loss) $1,027,751 $338,651 ($69,672 ) ($95,695 ) $1,201,035 Total assets as of September 30, 2016 $40,542,593 $9,100,779 $1,339,879 ($3,245,070 ) $47,738,181 2015 Operating revenues $7,401,136 $1,603,643 $— ($51 ) $9,004,728 Income taxes $407,993 ($487,622 ) ($37,783 ) $— ($117,412 ) Consolidated net income (loss) $796,051 ($911,524 ) ($50,415 ) ($95,695 ) ($261,583 ) Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. 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, 2016 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,649,392 $475,345 $— ($34 ) $3,124,703 Income taxes $255,603 $6,115 ($3,812 ) $— $257,906 Consolidated net income (loss) $447,782 $8,221 ($30,901 ) ($31,898 ) $393,204 2015 Operating revenues $2,849,681 $521,746 $— ($21 ) $3,371,406 Income taxes $198,945 ($554,513 ) ($12,097 ) $— ($367,665 ) Consolidated net income (loss) $364,265 ($1,031,410 ) ($19,190 ) ($31,898 ) ($718,233 ) Entergy’s segment financial information for the nine months ended September 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $6,855,664 $1,341,534 $— ($80 ) $8,197,118 Income taxes $359,653 ($176,626 ) ($34,148 ) $— $148,879 Consolidated net income (loss) $1,027,751 $338,651 ($69,672 ) ($95,695 ) $1,201,035 Total assets as of September 30, 2016 $40,542,593 $9,100,779 $1,339,879 ($3,245,070 ) $47,738,181 2015 Operating revenues $7,401,136 $1,603,643 $— ($51 ) $9,004,728 Income taxes $407,993 ($487,622 ) ($37,783 ) $— ($117,412 ) Consolidated net income (loss) $796,051 ($911,524 ) ($50,415 ) ($95,695 ) ($261,583 ) Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. 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, 2016 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,649,392 $475,345 $— ($34 ) $3,124,703 Income taxes $255,603 $6,115 ($3,812 ) $— $257,906 Consolidated net income (loss) $447,782 $8,221 ($30,901 ) ($31,898 ) $393,204 2015 Operating revenues $2,849,681 $521,746 $— ($21 ) $3,371,406 Income taxes $198,945 ($554,513 ) ($12,097 ) $— ($367,665 ) Consolidated net income (loss) $364,265 ($1,031,410 ) ($19,190 ) ($31,898 ) ($718,233 ) Entergy’s segment financial information for the nine months ended September 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $6,855,664 $1,341,534 $— ($80 ) $8,197,118 Income taxes $359,653 ($176,626 ) ($34,148 ) $— $148,879 Consolidated net income (loss) $1,027,751 $338,651 ($69,672 ) ($95,695 ) $1,201,035 Total assets as of September 30, 2016 $40,542,593 $9,100,779 $1,339,879 ($3,245,070 ) $47,738,181 2015 Operating revenues $7,401,136 $1,603,643 $— ($51 ) $9,004,728 Income taxes $407,993 ($487,622 ) ($37,783 ) $— ($117,412 ) Consolidated net income (loss) $796,051 ($911,524 ) ($50,415 ) ($95,695 ) ($261,583 ) Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. 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, 2016 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,649,392 $475,345 $— ($34 ) $3,124,703 Income taxes $255,603 $6,115 ($3,812 ) $— $257,906 Consolidated net income (loss) $447,782 $8,221 ($30,901 ) ($31,898 ) $393,204 2015 Operating revenues $2,849,681 $521,746 $— ($21 ) $3,371,406 Income taxes $198,945 ($554,513 ) ($12,097 ) $— ($367,665 ) Consolidated net income (loss) $364,265 ($1,031,410 ) ($19,190 ) ($31,898 ) ($718,233 ) Entergy’s segment financial information for the nine months ended September 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $6,855,664 $1,341,534 $— ($80 ) $8,197,118 Income taxes $359,653 ($176,626 ) ($34,148 ) $— $148,879 Consolidated net income (loss) $1,027,751 $338,651 ($69,672 ) ($95,695 ) $1,201,035 Total assets as of September 30, 2016 $40,542,593 $9,100,779 $1,339,879 ($3,245,070 ) $47,738,181 2015 Operating revenues $7,401,136 $1,603,643 $— ($51 ) $9,004,728 Income taxes $407,993 ($487,622 ) ($37,783 ) $— ($117,412 ) Consolidated net income (loss) $796,051 ($911,524 ) ($50,415 ) ($95,695 ) ($261,583 ) Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. 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, 2016 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,649,392 $475,345 $— ($34 ) $3,124,703 Income taxes $255,603 $6,115 ($3,812 ) $— $257,906 Consolidated net income (loss) $447,782 $8,221 ($30,901 ) ($31,898 ) $393,204 2015 Operating revenues $2,849,681 $521,746 $— ($21 ) $3,371,406 Income taxes $198,945 ($554,513 ) ($12,097 ) $— ($367,665 ) Consolidated net income (loss) $364,265 ($1,031,410 ) ($19,190 ) ($31,898 ) ($718,233 ) Entergy’s segment financial information for the nine months ended September 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $6,855,664 $1,341,534 $— ($80 ) $8,197,118 Income taxes $359,653 ($176,626 ) ($34,148 ) $— $148,879 Consolidated net income (loss) $1,027,751 $338,651 ($69,672 ) ($95,695 ) $1,201,035 Total assets as of September 30, 2016 $40,542,593 $9,100,779 $1,339,879 ($3,245,070 ) $47,738,181 2015 Operating revenues $7,401,136 $1,603,643 $— ($51 ) $9,004,728 Income taxes $407,993 ($487,622 ) ($37,783 ) $— ($117,412 ) Consolidated net income (loss) $796,051 ($911,524 ) ($50,415 ) ($95,695 ) ($261,583 ) Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. 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, 2016
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 is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2016 is approximately 2.25 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 90% for the remainder of 2016 , of which approximately 61% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2016 is 9 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, 2016 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $4 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of September 30, 2016, $4 million in cash collateral and letters of credit in the amount of $49 million were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). As of December 31, 2015, $9 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $68 million was required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate guarantee is typically ignored and 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, 2016 is 25,604,000 MMBtu for Entergy, including 18,780,000 MMBtu for Entergy Louisiana, 5,750,000 MMBtu for Entergy Mississippi, and 1,074,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests. During the second quarter 2016, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2016 through May 31, 2017. FTRs 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 FTRs 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 FTRs 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 FTRs. The total volume of FTRs outstanding as of September 30, 2016 is 74,491 GWh for Entergy, including 16,859 GWh for Entergy Arkansas, 31,476 GWh for Entergy Louisiana, 12,374 GWh for Entergy Mississippi, 3,640 GWh for Entergy New Orleans, and 9,745 GWh for Entergy Texas. Credit support for FTRs 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 FTRs held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities as of September 30, 2016 and December 31, 2015, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $67 ($17) $50 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($5) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $1 ($1) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $42 ($17) $25 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($1) $5 Entergy Wholesale Commodities FTRs Prepayments and other $32 ($1) $31 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $34 ($34) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2015 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $173 ($34) $139 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $17 ($2) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $14 ($14) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $54 ($13) $41 Entergy Wholesale Commodities FTRs Prepayments and other $24 ($1) $23 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $38 ($32) $6 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 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 Consolidated Balance Sheets (d) Excludes cash collateral in the amount of $4 million posted and $4 million held as of September 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $49 million held as of September 30, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $70 Competitive businesses operating revenues $37 2015 Electricity swaps and options $49 Competitive businesses operating revenues $86 (a) Before taxes of $13 million and $30 million for the three months ended September 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $156 Competitive businesses operating revenues $237 2015 Electricity swaps and options $154 Competitive businesses operating revenues $177 (a) Before taxes of $83 million and $61 million for the nine months ended September 30, 2016 and 2015, 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, 2016 and 2015 was $6.4 million and ($0.9) million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2016 and 2015 was $6.1 million and $0.1 million , respectively. Based on market prices as of September 30, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $85 million . Approximately $66 million is expected to be reclassified from AOCI to operating revenues in the next twelve months. The actual amount reclassified from AOCI, 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 statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $25 FTRs $— Purchased power expense (b) $37 Electricity swaps and options ($9) (c) Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) FTRs $— Purchased power expense (b) $51 Electricity swaps and options $— (c) Competitive business operating revenues ($3) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($5) FTRs $— Purchased power expense (b) $96 Electricity swaps and options $6 (c) Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($29) FTRs $— Purchased power expense (b) $130 Electricity swaps and options $1 (c) Competitive business operating revenues ($42) (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 FTRs 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 FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in AOCI 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, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $8.1 Entergy Arkansas FTRs Prepayments and other $12.4 Entergy Louisiana FTRs Prepayments and other $4.0 Entergy Mississippi FTRs Prepayments and other $1.6 Entergy New Orleans FTRs Prepayments and other $5.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $0.4 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2015 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $7.9 Entergy Arkansas FTRs Prepayments and other $8.5 Entergy Louisiana FTRs Prepayments and other $2.4 Entergy Mississippi FTRs Prepayments and other $1.5 Entergy New Orleans FTRs Prepayments and other $2.2 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.3 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 Entergy New Orleans (a) No cash collateral or letters of credit were required to be posted for FTR exposure as of September 30, 2016 and December 31, 2015, respectively. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $5.3 (a) Entergy Mississippi FTRs Purchased power expense $7.1 (b) Entergy Arkansas FTRs Purchased power expense $20.4 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $0.9 (b) Entergy New Orleans FTRs Purchased power expense $1.8 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($10.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans FTRs Purchased power expense $13.9 (b) Entergy Arkansas FTRs Purchased power expense $17.9 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $1.5 (b) Entergy New Orleans FTRs Purchased power expense $10.9 (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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.5) (a) Entergy New Orleans FTRs Purchased power expense $20.3 (b) Entergy Arkansas FTRs Purchased power expense $52.5 (b) Entergy Louisiana FTRs Purchased power expense $11.1 (b) Entergy Mississippi FTRs Purchased power expense $2.8 (b) Entergy New Orleans FTRs Purchased power expense $8.7 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($23.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.3) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy New Orleans FTRs Purchased power expense $48.6 (b) Entergy Arkansas FTRs Purchased power expense $49.7 (b) Entergy Louisiana FTRs Purchased power expense $13.9 (b) Entergy Mississippi FTRs Purchased power expense $7.5 (b) Entergy New Orleans FTRs Purchased power expense $10.7 (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 FTRs 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 FTRs 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. Effective first quarter 2016, Entergy retrospectively adopted ASU 2015-07, which simplifies the disclosure for fair value investments by removing the requirement to categorize within the fair value hierarchy investment for which fair value is measured using the net asset value per share as a practical expedient. For all periods presented the common trust funds have not been assigned a level and are presented within the fair value tables only as a reconciling item to the total fair value of investments. 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 FTRs 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options. The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available, and uses multiple sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity e
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 is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2016 is approximately 2.25 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 90% for the remainder of 2016 , of which approximately 61% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2016 is 9 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, 2016 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $4 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of September 30, 2016, $4 million in cash collateral and letters of credit in the amount of $49 million were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). As of December 31, 2015, $9 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $68 million was required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate guarantee is typically ignored and 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, 2016 is 25,604,000 MMBtu for Entergy, including 18,780,000 MMBtu for Entergy Louisiana, 5,750,000 MMBtu for Entergy Mississippi, and 1,074,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests. During the second quarter 2016, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2016 through May 31, 2017. FTRs 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 FTRs 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 FTRs 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 FTRs. The total volume of FTRs outstanding as of September 30, 2016 is 74,491 GWh for Entergy, including 16,859 GWh for Entergy Arkansas, 31,476 GWh for Entergy Louisiana, 12,374 GWh for Entergy Mississippi, 3,640 GWh for Entergy New Orleans, and 9,745 GWh for Entergy Texas. Credit support for FTRs 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 FTRs held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities as of September 30, 2016 and December 31, 2015, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $67 ($17) $50 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($5) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $1 ($1) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $42 ($17) $25 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($1) $5 Entergy Wholesale Commodities FTRs Prepayments and other $32 ($1) $31 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $34 ($34) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2015 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $173 ($34) $139 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $17 ($2) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $14 ($14) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $54 ($13) $41 Entergy Wholesale Commodities FTRs Prepayments and other $24 ($1) $23 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $38 ($32) $6 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 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 Consolidated Balance Sheets (d) Excludes cash collateral in the amount of $4 million posted and $4 million held as of September 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $49 million held as of September 30, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $70 Competitive businesses operating revenues $37 2015 Electricity swaps and options $49 Competitive businesses operating revenues $86 (a) Before taxes of $13 million and $30 million for the three months ended September 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $156 Competitive businesses operating revenues $237 2015 Electricity swaps and options $154 Competitive businesses operating revenues $177 (a) Before taxes of $83 million and $61 million for the nine months ended September 30, 2016 and 2015, 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, 2016 and 2015 was $6.4 million and ($0.9) million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2016 and 2015 was $6.1 million and $0.1 million , respectively. Based on market prices as of September 30, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $85 million . Approximately $66 million is expected to be reclassified from AOCI to operating revenues in the next twelve months. The actual amount reclassified from AOCI, 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 statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $25 FTRs $— Purchased power expense (b) $37 Electricity swaps and options ($9) (c) Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) FTRs $— Purchased power expense (b) $51 Electricity swaps and options $— (c) Competitive business operating revenues ($3) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($5) FTRs $— Purchased power expense (b) $96 Electricity swaps and options $6 (c) Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($29) FTRs $— Purchased power expense (b) $130 Electricity swaps and options $1 (c) Competitive business operating revenues ($42) (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 FTRs 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 FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in AOCI 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, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $8.1 Entergy Arkansas FTRs Prepayments and other $12.4 Entergy Louisiana FTRs Prepayments and other $4.0 Entergy Mississippi FTRs Prepayments and other $1.6 Entergy New Orleans FTRs Prepayments and other $5.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $0.4 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2015 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $7.9 Entergy Arkansas FTRs Prepayments and other $8.5 Entergy Louisiana FTRs Prepayments and other $2.4 Entergy Mississippi FTRs Prepayments and other $1.5 Entergy New Orleans FTRs Prepayments and other $2.2 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.3 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 Entergy New Orleans (a) No cash collateral or letters of credit were required to be posted for FTR exposure as of September 30, 2016 and December 31, 2015, respectively. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $5.3 (a) Entergy Mississippi FTRs Purchased power expense $7.1 (b) Entergy Arkansas FTRs Purchased power expense $20.4 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $0.9 (b) Entergy New Orleans FTRs Purchased power expense $1.8 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($10.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans FTRs Purchased power expense $13.9 (b) Entergy Arkansas FTRs Purchased power expense $17.9 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $1.5 (b) Entergy New Orleans FTRs Purchased power expense $10.9 (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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.5) (a) Entergy New Orleans FTRs Purchased power expense $20.3 (b) Entergy Arkansas FTRs Purchased power expense $52.5 (b) Entergy Louisiana FTRs Purchased power expense $11.1 (b) Entergy Mississippi FTRs Purchased power expense $2.8 (b) Entergy New Orleans FTRs Purchased power expense $8.7 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($23.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.3) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy New Orleans FTRs Purchased power expense $48.6 (b) Entergy Arkansas FTRs Purchased power expense $49.7 (b) Entergy Louisiana FTRs Purchased power expense $13.9 (b) Entergy Mississippi FTRs Purchased power expense $7.5 (b) Entergy New Orleans FTRs Purchased power expense $10.7 (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 FTRs 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 FTRs 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. Effective first quarter 2016, Entergy retrospectively adopted ASU 2015-07, which simplifies the disclosure for fair value investments by removing the requirement to categorize within the fair value hierarchy investment for which fair value is measured using the net asset value per share as a practical expedient. For all periods presented the common trust funds have not been assigned a level and are presented within the fair value tables only as a reconciling item to the total fair value of investments. 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 FTRs 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options. The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available, and uses multiple sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity e
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 is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2016 is approximately 2.25 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 90% for the remainder of 2016 , of which approximately 61% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2016 is 9 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, 2016 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $4 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of September 30, 2016, $4 million in cash collateral and letters of credit in the amount of $49 million were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). As of December 31, 2015, $9 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $68 million was required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate guarantee is typically ignored and 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, 2016 is 25,604,000 MMBtu for Entergy, including 18,780,000 MMBtu for Entergy Louisiana, 5,750,000 MMBtu for Entergy Mississippi, and 1,074,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests. During the second quarter 2016, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2016 through May 31, 2017. FTRs 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 FTRs 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 FTRs 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 FTRs. The total volume of FTRs outstanding as of September 30, 2016 is 74,491 GWh for Entergy, including 16,859 GWh for Entergy Arkansas, 31,476 GWh for Entergy Louisiana, 12,374 GWh for Entergy Mississippi, 3,640 GWh for Entergy New Orleans, and 9,745 GWh for Entergy Texas. Credit support for FTRs 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 FTRs held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities as of September 30, 2016 and December 31, 2015, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $67 ($17) $50 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($5) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $1 ($1) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $42 ($17) $25 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($1) $5 Entergy Wholesale Commodities FTRs Prepayments and other $32 ($1) $31 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $34 ($34) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2015 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $173 ($34) $139 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $17 ($2) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $14 ($14) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $54 ($13) $41 Entergy Wholesale Commodities FTRs Prepayments and other $24 ($1) $23 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $38 ($32) $6 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 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 Consolidated Balance Sheets (d) Excludes cash collateral in the amount of $4 million posted and $4 million held as of September 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $49 million held as of September 30, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $70 Competitive businesses operating revenues $37 2015 Electricity swaps and options $49 Competitive businesses operating revenues $86 (a) Before taxes of $13 million and $30 million for the three months ended September 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $156 Competitive businesses operating revenues $237 2015 Electricity swaps and options $154 Competitive businesses operating revenues $177 (a) Before taxes of $83 million and $61 million for the nine months ended September 30, 2016 and 2015, 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, 2016 and 2015 was $6.4 million and ($0.9) million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2016 and 2015 was $6.1 million and $0.1 million , respectively. Based on market prices as of September 30, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $85 million . Approximately $66 million is expected to be reclassified from AOCI to operating revenues in the next twelve months. The actual amount reclassified from AOCI, 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 statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $25 FTRs $— Purchased power expense (b) $37 Electricity swaps and options ($9) (c) Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) FTRs $— Purchased power expense (b) $51 Electricity swaps and options $— (c) Competitive business operating revenues ($3) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($5) FTRs $— Purchased power expense (b) $96 Electricity swaps and options $6 (c) Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($29) FTRs $— Purchased power expense (b) $130 Electricity swaps and options $1 (c) Competitive business operating revenues ($42) (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 FTRs 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 FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in AOCI 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, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $8.1 Entergy Arkansas FTRs Prepayments and other $12.4 Entergy Louisiana FTRs Prepayments and other $4.0 Entergy Mississippi FTRs Prepayments and other $1.6 Entergy New Orleans FTRs Prepayments and other $5.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $0.4 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2015 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $7.9 Entergy Arkansas FTRs Prepayments and other $8.5 Entergy Louisiana FTRs Prepayments and other $2.4 Entergy Mississippi FTRs Prepayments and other $1.5 Entergy New Orleans FTRs Prepayments and other $2.2 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.3 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 Entergy New Orleans (a) No cash collateral or letters of credit were required to be posted for FTR exposure as of September 30, 2016 and December 31, 2015, respectively. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $5.3 (a) Entergy Mississippi FTRs Purchased power expense $7.1 (b) Entergy Arkansas FTRs Purchased power expense $20.4 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $0.9 (b) Entergy New Orleans FTRs Purchased power expense $1.8 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($10.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans FTRs Purchased power expense $13.9 (b) Entergy Arkansas FTRs Purchased power expense $17.9 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $1.5 (b) Entergy New Orleans FTRs Purchased power expense $10.9 (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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.5) (a) Entergy New Orleans FTRs Purchased power expense $20.3 (b) Entergy Arkansas FTRs Purchased power expense $52.5 (b) Entergy Louisiana FTRs Purchased power expense $11.1 (b) Entergy Mississippi FTRs Purchased power expense $2.8 (b) Entergy New Orleans FTRs Purchased power expense $8.7 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($23.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.3) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy New Orleans FTRs Purchased power expense $48.6 (b) Entergy Arkansas FTRs Purchased power expense $49.7 (b) Entergy Louisiana FTRs Purchased power expense $13.9 (b) Entergy Mississippi FTRs Purchased power expense $7.5 (b) Entergy New Orleans FTRs Purchased power expense $10.7 (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 FTRs 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 FTRs 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. Effective first quarter 2016, Entergy retrospectively adopted ASU 2015-07, which simplifies the disclosure for fair value investments by removing the requirement to categorize within the fair value hierarchy investment for which fair value is measured using the net asset value per share as a practical expedient. For all periods presented the common trust funds have not been assigned a level and are presented within the fair value tables only as a reconciling item to the total fair value of investments. 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 FTRs 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options. The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available, and uses multiple sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity e
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 is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2016 is approximately 2.25 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 90% for the remainder of 2016 , of which approximately 61% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2016 is 9 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, 2016 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $4 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of September 30, 2016, $4 million in cash collateral and letters of credit in the amount of $49 million were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). As of December 31, 2015, $9 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $68 million was required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate guarantee is typically ignored and 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, 2016 is 25,604,000 MMBtu for Entergy, including 18,780,000 MMBtu for Entergy Louisiana, 5,750,000 MMBtu for Entergy Mississippi, and 1,074,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests. During the second quarter 2016, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2016 through May 31, 2017. FTRs 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 FTRs 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 FTRs 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 FTRs. The total volume of FTRs outstanding as of September 30, 2016 is 74,491 GWh for Entergy, including 16,859 GWh for Entergy Arkansas, 31,476 GWh for Entergy Louisiana, 12,374 GWh for Entergy Mississippi, 3,640 GWh for Entergy New Orleans, and 9,745 GWh for Entergy Texas. Credit support for FTRs 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 FTRs held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities as of September 30, 2016 and December 31, 2015, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $67 ($17) $50 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($5) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $1 ($1) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $42 ($17) $25 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($1) $5 Entergy Wholesale Commodities FTRs Prepayments and other $32 ($1) $31 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $34 ($34) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2015 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $173 ($34) $139 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $17 ($2) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $14 ($14) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $54 ($13) $41 Entergy Wholesale Commodities FTRs Prepayments and other $24 ($1) $23 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $38 ($32) $6 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 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 Consolidated Balance Sheets (d) Excludes cash collateral in the amount of $4 million posted and $4 million held as of September 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $49 million held as of September 30, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $70 Competitive businesses operating revenues $37 2015 Electricity swaps and options $49 Competitive businesses operating revenues $86 (a) Before taxes of $13 million and $30 million for the three months ended September 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $156 Competitive businesses operating revenues $237 2015 Electricity swaps and options $154 Competitive businesses operating revenues $177 (a) Before taxes of $83 million and $61 million for the nine months ended September 30, 2016 and 2015, 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, 2016 and 2015 was $6.4 million and ($0.9) million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2016 and 2015 was $6.1 million and $0.1 million , respectively. Based on market prices as of September 30, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $85 million . Approximately $66 million is expected to be reclassified from AOCI to operating revenues in the next twelve months. The actual amount reclassified from AOCI, 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 statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $25 FTRs $— Purchased power expense (b) $37 Electricity swaps and options ($9) (c) Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) FTRs $— Purchased power expense (b) $51 Electricity swaps and options $— (c) Competitive business operating revenues ($3) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($5) FTRs $— Purchased power expense (b) $96 Electricity swaps and options $6 (c) Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($29) FTRs $— Purchased power expense (b) $130 Electricity swaps and options $1 (c) Competitive business operating revenues ($42) (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 FTRs 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 FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in AOCI 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, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $8.1 Entergy Arkansas FTRs Prepayments and other $12.4 Entergy Louisiana FTRs Prepayments and other $4.0 Entergy Mississippi FTRs Prepayments and other $1.6 Entergy New Orleans FTRs Prepayments and other $5.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $0.4 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2015 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $7.9 Entergy Arkansas FTRs Prepayments and other $8.5 Entergy Louisiana FTRs Prepayments and other $2.4 Entergy Mississippi FTRs Prepayments and other $1.5 Entergy New Orleans FTRs Prepayments and other $2.2 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.3 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 Entergy New Orleans (a) No cash collateral or letters of credit were required to be posted for FTR exposure as of September 30, 2016 and December 31, 2015, respectively. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $5.3 (a) Entergy Mississippi FTRs Purchased power expense $7.1 (b) Entergy Arkansas FTRs Purchased power expense $20.4 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $0.9 (b) Entergy New Orleans FTRs Purchased power expense $1.8 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($10.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans FTRs Purchased power expense $13.9 (b) Entergy Arkansas FTRs Purchased power expense $17.9 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $1.5 (b) Entergy New Orleans FTRs Purchased power expense $10.9 (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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.5) (a) Entergy New Orleans FTRs Purchased power expense $20.3 (b) Entergy Arkansas FTRs Purchased power expense $52.5 (b) Entergy Louisiana FTRs Purchased power expense $11.1 (b) Entergy Mississippi FTRs Purchased power expense $2.8 (b) Entergy New Orleans FTRs Purchased power expense $8.7 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($23.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.3) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy New Orleans FTRs Purchased power expense $48.6 (b) Entergy Arkansas FTRs Purchased power expense $49.7 (b) Entergy Louisiana FTRs Purchased power expense $13.9 (b) Entergy Mississippi FTRs Purchased power expense $7.5 (b) Entergy New Orleans FTRs Purchased power expense $10.7 (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 FTRs 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 FTRs 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. Effective first quarter 2016, Entergy retrospectively adopted ASU 2015-07, which simplifies the disclosure for fair value investments by removing the requirement to categorize within the fair value hierarchy investment for which fair value is measured using the net asset value per share as a practical expedient. For all periods presented the common trust funds have not been assigned a level and are presented within the fair value tables only as a reconciling item to the total fair value of investments. 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 FTRs 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options. The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available, and uses multiple sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity e
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 is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2016 is approximately 2.25 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 90% for the remainder of 2016 , of which approximately 61% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2016 is 9 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, 2016 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $4 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of September 30, 2016, $4 million in cash collateral and letters of credit in the amount of $49 million were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). As of December 31, 2015, $9 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $68 million was required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate guarantee is typically ignored and 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, 2016 is 25,604,000 MMBtu for Entergy, including 18,780,000 MMBtu for Entergy Louisiana, 5,750,000 MMBtu for Entergy Mississippi, and 1,074,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests. During the second quarter 2016, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2016 through May 31, 2017. FTRs 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 FTRs 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 FTRs 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 FTRs. The total volume of FTRs outstanding as of September 30, 2016 is 74,491 GWh for Entergy, including 16,859 GWh for Entergy Arkansas, 31,476 GWh for Entergy Louisiana, 12,374 GWh for Entergy Mississippi, 3,640 GWh for Entergy New Orleans, and 9,745 GWh for Entergy Texas. Credit support for FTRs 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 FTRs held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities as of September 30, 2016 and December 31, 2015, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $67 ($17) $50 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($5) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $1 ($1) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $42 ($17) $25 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($1) $5 Entergy Wholesale Commodities FTRs Prepayments and other $32 ($1) $31 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $34 ($34) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2015 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $173 ($34) $139 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $17 ($2) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $14 ($14) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $54 ($13) $41 Entergy Wholesale Commodities FTRs Prepayments and other $24 ($1) $23 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $38 ($32) $6 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 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 Consolidated Balance Sheets (d) Excludes cash collateral in the amount of $4 million posted and $4 million held as of September 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $49 million held as of September 30, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $70 Competitive businesses operating revenues $37 2015 Electricity swaps and options $49 Competitive businesses operating revenues $86 (a) Before taxes of $13 million and $30 million for the three months ended September 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $156 Competitive businesses operating revenues $237 2015 Electricity swaps and options $154 Competitive businesses operating revenues $177 (a) Before taxes of $83 million and $61 million for the nine months ended September 30, 2016 and 2015, 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, 2016 and 2015 was $6.4 million and ($0.9) million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2016 and 2015 was $6.1 million and $0.1 million , respectively. Based on market prices as of September 30, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $85 million . Approximately $66 million is expected to be reclassified from AOCI to operating revenues in the next twelve months. The actual amount reclassified from AOCI, 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 statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $25 FTRs $— Purchased power expense (b) $37 Electricity swaps and options ($9) (c) Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) FTRs $— Purchased power expense (b) $51 Electricity swaps and options $— (c) Competitive business operating revenues ($3) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($5) FTRs $— Purchased power expense (b) $96 Electricity swaps and options $6 (c) Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($29) FTRs $— Purchased power expense (b) $130 Electricity swaps and options $1 (c) Competitive business operating revenues ($42) (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 FTRs 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 FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in AOCI 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, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $8.1 Entergy Arkansas FTRs Prepayments and other $12.4 Entergy Louisiana FTRs Prepayments and other $4.0 Entergy Mississippi FTRs Prepayments and other $1.6 Entergy New Orleans FTRs Prepayments and other $5.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $0.4 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2015 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $7.9 Entergy Arkansas FTRs Prepayments and other $8.5 Entergy Louisiana FTRs Prepayments and other $2.4 Entergy Mississippi FTRs Prepayments and other $1.5 Entergy New Orleans FTRs Prepayments and other $2.2 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.3 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 Entergy New Orleans (a) No cash collateral or letters of credit were required to be posted for FTR exposure as of September 30, 2016 and December 31, 2015, respectively. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $5.3 (a) Entergy Mississippi FTRs Purchased power expense $7.1 (b) Entergy Arkansas FTRs Purchased power expense $20.4 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $0.9 (b) Entergy New Orleans FTRs Purchased power expense $1.8 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($10.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans FTRs Purchased power expense $13.9 (b) Entergy Arkansas FTRs Purchased power expense $17.9 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $1.5 (b) Entergy New Orleans FTRs Purchased power expense $10.9 (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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.5) (a) Entergy New Orleans FTRs Purchased power expense $20.3 (b) Entergy Arkansas FTRs Purchased power expense $52.5 (b) Entergy Louisiana FTRs Purchased power expense $11.1 (b) Entergy Mississippi FTRs Purchased power expense $2.8 (b) Entergy New Orleans FTRs Purchased power expense $8.7 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($23.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.3) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy New Orleans FTRs Purchased power expense $48.6 (b) Entergy Arkansas FTRs Purchased power expense $49.7 (b) Entergy Louisiana FTRs Purchased power expense $13.9 (b) Entergy Mississippi FTRs Purchased power expense $7.5 (b) Entergy New Orleans FTRs Purchased power expense $10.7 (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 FTRs 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 FTRs 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. Effective first quarter 2016, Entergy retrospectively adopted ASU 2015-07, which simplifies the disclosure for fair value investments by removing the requirement to categorize within the fair value hierarchy investment for which fair value is measured using the net asset value per share as a practical expedient. For all periods presented the common trust funds have not been assigned a level and are presented within the fair value tables only as a reconciling item to the total fair value of investments. 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 FTRs 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options. The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available, and uses multiple sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity e
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 is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2016 is approximately 2.25 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 90% for the remainder of 2016 , of which approximately 61% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2016 is 9 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, 2016 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $4 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of September 30, 2016, $4 million in cash collateral and letters of credit in the amount of $49 million were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). As of December 31, 2015, $9 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $68 million was required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate guarantee is typically ignored and 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, 2016 is 25,604,000 MMBtu for Entergy, including 18,780,000 MMBtu for Entergy Louisiana, 5,750,000 MMBtu for Entergy Mississippi, and 1,074,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests. During the second quarter 2016, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2016 through May 31, 2017. FTRs 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 FTRs 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 FTRs 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 FTRs. The total volume of FTRs outstanding as of September 30, 2016 is 74,491 GWh for Entergy, including 16,859 GWh for Entergy Arkansas, 31,476 GWh for Entergy Louisiana, 12,374 GWh for Entergy Mississippi, 3,640 GWh for Entergy New Orleans, and 9,745 GWh for Entergy Texas. Credit support for FTRs 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 FTRs held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities as of September 30, 2016 and December 31, 2015, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $67 ($17) $50 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($5) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $1 ($1) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $42 ($17) $25 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($1) $5 Entergy Wholesale Commodities FTRs Prepayments and other $32 ($1) $31 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $34 ($34) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2015 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $173 ($34) $139 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $17 ($2) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $14 ($14) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $54 ($13) $41 Entergy Wholesale Commodities FTRs Prepayments and other $24 ($1) $23 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $38 ($32) $6 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 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 Consolidated Balance Sheets (d) Excludes cash collateral in the amount of $4 million posted and $4 million held as of September 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $49 million held as of September 30, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $70 Competitive businesses operating revenues $37 2015 Electricity swaps and options $49 Competitive businesses operating revenues $86 (a) Before taxes of $13 million and $30 million for the three months ended September 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $156 Competitive businesses operating revenues $237 2015 Electricity swaps and options $154 Competitive businesses operating revenues $177 (a) Before taxes of $83 million and $61 million for the nine months ended September 30, 2016 and 2015, 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, 2016 and 2015 was $6.4 million and ($0.9) million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2016 and 2015 was $6.1 million and $0.1 million , respectively. Based on market prices as of September 30, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $85 million . Approximately $66 million is expected to be reclassified from AOCI to operating revenues in the next twelve months. The actual amount reclassified from AOCI, 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 statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $25 FTRs $— Purchased power expense (b) $37 Electricity swaps and options ($9) (c) Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) FTRs $— Purchased power expense (b) $51 Electricity swaps and options $— (c) Competitive business operating revenues ($3) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($5) FTRs $— Purchased power expense (b) $96 Electricity swaps and options $6 (c) Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($29) FTRs $— Purchased power expense (b) $130 Electricity swaps and options $1 (c) Competitive business operating revenues ($42) (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 FTRs 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 FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in AOCI 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, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $8.1 Entergy Arkansas FTRs Prepayments and other $12.4 Entergy Louisiana FTRs Prepayments and other $4.0 Entergy Mississippi FTRs Prepayments and other $1.6 Entergy New Orleans FTRs Prepayments and other $5.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $0.4 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2015 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $7.9 Entergy Arkansas FTRs Prepayments and other $8.5 Entergy Louisiana FTRs Prepayments and other $2.4 Entergy Mississippi FTRs Prepayments and other $1.5 Entergy New Orleans FTRs Prepayments and other $2.2 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.3 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 Entergy New Orleans (a) No cash collateral or letters of credit were required to be posted for FTR exposure as of September 30, 2016 and December 31, 2015, respectively. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $5.3 (a) Entergy Mississippi FTRs Purchased power expense $7.1 (b) Entergy Arkansas FTRs Purchased power expense $20.4 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $0.9 (b) Entergy New Orleans FTRs Purchased power expense $1.8 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($10.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans FTRs Purchased power expense $13.9 (b) Entergy Arkansas FTRs Purchased power expense $17.9 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $1.5 (b) Entergy New Orleans FTRs Purchased power expense $10.9 (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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.5) (a) Entergy New Orleans FTRs Purchased power expense $20.3 (b) Entergy Arkansas FTRs Purchased power expense $52.5 (b) Entergy Louisiana FTRs Purchased power expense $11.1 (b) Entergy Mississippi FTRs Purchased power expense $2.8 (b) Entergy New Orleans FTRs Purchased power expense $8.7 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($23.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.3) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy New Orleans FTRs Purchased power expense $48.6 (b) Entergy Arkansas FTRs Purchased power expense $49.7 (b) Entergy Louisiana FTRs Purchased power expense $13.9 (b) Entergy Mississippi FTRs Purchased power expense $7.5 (b) Entergy New Orleans FTRs Purchased power expense $10.7 (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 FTRs 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 FTRs 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. Effective first quarter 2016, Entergy retrospectively adopted ASU 2015-07, which simplifies the disclosure for fair value investments by removing the requirement to categorize within the fair value hierarchy investment for which fair value is measured using the net asset value per share as a practical expedient. For all periods presented the common trust funds have not been assigned a level and are presented within the fair value tables only as a reconciling item to the total fair value of investments. 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 FTRs 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options. The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available, and uses multiple sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity e
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 is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2016 is approximately 2.25 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 90% for the remainder of 2016 , of which approximately 61% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2016 is 9 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, 2016 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $4 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of September 30, 2016, $4 million in cash collateral and letters of credit in the amount of $49 million were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). As of December 31, 2015, $9 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $68 million was required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate guarantee is typically ignored and 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, 2016 is 25,604,000 MMBtu for Entergy, including 18,780,000 MMBtu for Entergy Louisiana, 5,750,000 MMBtu for Entergy Mississippi, and 1,074,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests. During the second quarter 2016, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2016 through May 31, 2017. FTRs 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 FTRs 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 FTRs 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 FTRs. The total volume of FTRs outstanding as of September 30, 2016 is 74,491 GWh for Entergy, including 16,859 GWh for Entergy Arkansas, 31,476 GWh for Entergy Louisiana, 12,374 GWh for Entergy Mississippi, 3,640 GWh for Entergy New Orleans, and 9,745 GWh for Entergy Texas. Credit support for FTRs 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 FTRs held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities as of September 30, 2016 and December 31, 2015, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $67 ($17) $50 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($5) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $1 ($1) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $42 ($17) $25 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($1) $5 Entergy Wholesale Commodities FTRs Prepayments and other $32 ($1) $31 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $34 ($34) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2015 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $173 ($34) $139 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $17 ($2) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $14 ($14) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $54 ($13) $41 Entergy Wholesale Commodities FTRs Prepayments and other $24 ($1) $23 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $38 ($32) $6 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 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 Consolidated Balance Sheets (d) Excludes cash collateral in the amount of $4 million posted and $4 million held as of September 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $49 million held as of September 30, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $70 Competitive businesses operating revenues $37 2015 Electricity swaps and options $49 Competitive businesses operating revenues $86 (a) Before taxes of $13 million and $30 million for the three months ended September 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $156 Competitive businesses operating revenues $237 2015 Electricity swaps and options $154 Competitive businesses operating revenues $177 (a) Before taxes of $83 million and $61 million for the nine months ended September 30, 2016 and 2015, 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, 2016 and 2015 was $6.4 million and ($0.9) million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2016 and 2015 was $6.1 million and $0.1 million , respectively. Based on market prices as of September 30, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $85 million . Approximately $66 million is expected to be reclassified from AOCI to operating revenues in the next twelve months. The actual amount reclassified from AOCI, 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 statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $25 FTRs $— Purchased power expense (b) $37 Electricity swaps and options ($9) (c) Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) FTRs $— Purchased power expense (b) $51 Electricity swaps and options $— (c) Competitive business operating revenues ($3) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($5) FTRs $— Purchased power expense (b) $96 Electricity swaps and options $6 (c) Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($29) FTRs $— Purchased power expense (b) $130 Electricity swaps and options $1 (c) Competitive business operating revenues ($42) (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 FTRs 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 FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in AOCI 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, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $8.1 Entergy Arkansas FTRs Prepayments and other $12.4 Entergy Louisiana FTRs Prepayments and other $4.0 Entergy Mississippi FTRs Prepayments and other $1.6 Entergy New Orleans FTRs Prepayments and other $5.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $0.4 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2015 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $7.9 Entergy Arkansas FTRs Prepayments and other $8.5 Entergy Louisiana FTRs Prepayments and other $2.4 Entergy Mississippi FTRs Prepayments and other $1.5 Entergy New Orleans FTRs Prepayments and other $2.2 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.3 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 Entergy New Orleans (a) No cash collateral or letters of credit were required to be posted for FTR exposure as of September 30, 2016 and December 31, 2015, respectively. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $5.3 (a) Entergy Mississippi FTRs Purchased power expense $7.1 (b) Entergy Arkansas FTRs Purchased power expense $20.4 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $0.9 (b) Entergy New Orleans FTRs Purchased power expense $1.8 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($10.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans FTRs Purchased power expense $13.9 (b) Entergy Arkansas FTRs Purchased power expense $17.9 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $1.5 (b) Entergy New Orleans FTRs Purchased power expense $10.9 (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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.5) (a) Entergy New Orleans FTRs Purchased power expense $20.3 (b) Entergy Arkansas FTRs Purchased power expense $52.5 (b) Entergy Louisiana FTRs Purchased power expense $11.1 (b) Entergy Mississippi FTRs Purchased power expense $2.8 (b) Entergy New Orleans FTRs Purchased power expense $8.7 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($23.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.3) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy New Orleans FTRs Purchased power expense $48.6 (b) Entergy Arkansas FTRs Purchased power expense $49.7 (b) Entergy Louisiana FTRs Purchased power expense $13.9 (b) Entergy Mississippi FTRs Purchased power expense $7.5 (b) Entergy New Orleans FTRs Purchased power expense $10.7 (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 FTRs 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 FTRs 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. Effective first quarter 2016, Entergy retrospectively adopted ASU 2015-07, which simplifies the disclosure for fair value investments by removing the requirement to categorize within the fair value hierarchy investment for which fair value is measured using the net asset value per share as a practical expedient. For all periods presented the common trust funds have not been assigned a level and are presented within the fair value tables only as a reconciling item to the total fair value of investments. 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 FTRs 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options. The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available, and uses multiple sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity e

Decommissioning Trust Funds

Decommissioning Trust Funds	9 Months Ended
	Sep. 30, 2016
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) Entergy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The NRC requires Entergy subsidiaries to maintain trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades. The funds are invested primarily in equity securities, fixed-rate debt securities, and cash and cash equivalents. As discussed in Note 9 to the financial statements in the Form 10-K, when Entergy purchased the Indian Point 3 and FitzPatrick plants in 2000 from NYPA, NYPA retained the decommissioning trusts and the decommissioning liabilities. NYPA and Entergy subsidiaries executed decommissioning agreements, which specified their decommissioning obligations. At the time of the acquisition of the plants Entergy recorded a contract asset that represented an estimate of the present value of the difference between the stipulated contract amount for decommissioning the plants less the decommissioning costs estimated in independent decommissioning cost studies. In August 2016, Entergy entered into a trust transfer agreement with NYPA to transfer the decommissioning trusts and decommissioning liabilities for the Indian Point 3 and FitzPatrick plants to Entergy. The transaction is contingent upon receiving approval from the NRC. As a result of the agreement with NYPA, in the third quarter 2016, Entergy removed the contract asset from its balance sheet, and recorded receivables of $1.5 billion for the beneficial interests in the decommissioning trust funds and recorded asset retirement obligations for the decommissioning liabilities. At September 30, 2016, the fair value of the decommissioning trust funds held by NYPA was $1.5 billion . The fair value is based on the trust statements received from NYPA and is valued by the fund administrator using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value hierarchy. The receivables for the beneficial interests in the decommissioning trust funds are recorded in other deferred debits on the consolidated balance sheet. 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 has recorded an offsetting amount of unrealized gains/(losses) in other deferred credits. Decommissioning trust funds for Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains recorded on the assets in these trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity because these assets are classified as available-for-sale. Unrealized losses (where cost exceeds fair market value) on the assets in these 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. Generally, Entergy records realized gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,380 $1,568 $1 Debt Securities 2,291 94 2 Total $5,671 $1,662 $3 Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2015 Equity Securities $3,195 $1,396 $2 Debt Securities 2,155 41 17 Total $5,350 $1,437 $19 Deferred taxes on unrealized gains/(losses) are recorded in other comprehensive income for the decommissioning trusts which do not meet the criteria for regulatory accounting treatment as described above. Unrealized gains/(losses) above are reported before deferred taxes of $400 million and $342 million as of September 30, 2016 and December 31, 2015 , respectively. The amortized cost of debt securities was $2,199 million as of September 30, 2016 and $2,124 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 3.19% , an average duration of approximately 5.96 years, and an average maturity of approximately 9.39 years. 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 fair value and gross unrealized losses of available-for-sale equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $13 $1 $266 $1 More than 12 months — — 23 1 Total $13 $1 $289 $2 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $54 $2 $1,031 $15 More than 12 months 1 — 61 2 Total $55 $2 $1,092 $17 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $102 $77 1 year - 5 years 812 857 5 years - 10 years 743 704 10 years - 15 years 128 124 15 years - 20 years 62 50 20 years+ 444 343 Total $2,291 $2,155 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $564 million and $539 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $6 million and $13 million , respectively, and gross losses of $1 million and $4 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $1,797 million and $1,488 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $26 million and $58 million , respectively, and gross losses of $6 million and $7 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. Entergy Arkansas Entergy Arkansas holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $504.9 $263.4 $— Debt Securities 318.9 10.8 0.3 Total $823.8 $274.2 $0.3 2015 Equity Securities $467.4 $234.4 $0.2 Debt Securities 303.9 4.1 2.2 Total $771.3 $238.5 $2.4 The amortized cost of debt securities was $308.4 million as of September 30, 2016 and $301.8 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 2.63% , an average duration of approximately 5.21 years, and an average maturity of approximately 5.97 years. 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 equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $0.9 $— $32.5 $0.3 More than 12 months — — — — Total $0.9 $— $32.5 $0.3 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $7.8 $0.2 $111.4 $1.7 More than 12 months — — 18.5 0.5 Total $7.8 $0.2 $129.9 $2.2 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $8.8 $1.8 1 year - 5 years 123.5 145.2 5 years - 10 years 166.1 138.5 10 years - 15 years 9.5 2.4 15 years - 20 years 1.1 2.0 20 years+ 9.9 14.0 Total $318.9 $303.9 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $61.2 million and $44 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $0.4 million and $0.4 million , respectively, and gross losses of $0.04 million and $0.1 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $165 million and $190.8 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $1.6 million and $5.8 million , respectively, and gross losses of $0.3 million and $0.1 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $684.7 $322.9 $— Debt Securities 440.1 21.4 0.4 Total $1,124.8 $344.3 $0.4 2015 Equity Securities $632.4 $283.7 $0.2 Debt Securities 409.9 13.2 2.4 Total $1,042.3 $296.9 $2.6 The amortized cost of debt securities was $419.2 million as of September 30, 2016 and $399.2 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 3.83% , an average duration of approximately 5.72 years, and an average maturity of approximately 11.39 years. 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 equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $2.3 $— $32.5 $0.2 More than 12 months — — 6.5 0.2 Total $2.3 $— $39.0 $0.4 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $9.4 $0.2 $124.0 $2.0 More than 12 months — — 7.4 0.4 Total $9.4 $0.2 $131.4 $2.4 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $25.0 $27.1 1 year - 5 years 102.3 124.0 5 years - 10 years 121.5 114.3 10 years - 15 years 51.0 39.3 15 years - 20 years 31.1 26.5 20 years+ 109.2 78.7 Total $440.1 $409.9 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $54.7 million and $28.4 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $0.4 million and $0.2 million , respectively, and gross losses of $0.1 million and $0.1 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $178.2 million and $93.6 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $3 million and $1.7 million , respectively, and gross losses of $0.2 million and $0.3 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $456.3 $205.5 $0.1 Debt Securities 308.6 6.7 0.3 Total $764.9 $212.2 $0.4 2015 Equity Securities $423.7 $179.2 $0.3 Debt Securities 277.8 2.2 2.3 Total $701.5 $181.4 $2.6 The amortized cost of debt securities was $302.3 million as of September 30, 2016 and $270.7 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 1.79% , an average duration of approximately 5.18 years, and an average maturity of approximately 6.32 years. 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 equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $0.8 $— $81.4 $0.2 More than 12 months — 0.1 1.0 0.1 Total $0.8 $0.1 $82.4 $0.3 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8.3 $0.2 $200.4 $2.2 More than 12 months 0.9 0.1 5.0 0.1 Total $9.2 $0.3 $205.4 $2.3 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $3.0 $2.0 1 year - 5 years 192.6 181.2 5 years - 10 years 76.2 63.0 10 years - 15 years 3.5 4.4 15 years - 20 years 1.5 1.6 20 years+ 31.8 25.6 Total $308.6 $277.8 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $103.5 million and $163.4 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $0.7 million and $2.4 million , respectively, and gross losses of $0.06 million and $0.2 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $392.9 million and $325.4 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $3.2 million and $3.2 million , respectively, and gross losses of $0.4 million and $0.3 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy evaluate 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, 2016 and 2015 . The assessment of whether an investment in an equity security has suffered an other-than-temporary impairment continues to be based on a number of factors including, first, whether Entergy has the ability and intent to hold the investment to recover its value, the duration and severity of any losses, and, then, whether it is expected that the investment will recover its value within a reasonable period of time. 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 did not have any material charges relating to other-than-temporary impairment of certain equity securities for the three and nine months ended September 30, 2016 and 2015 .
Entergy Arkansas [Member]
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) Entergy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The NRC requires Entergy subsidiaries to maintain trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades. The funds are invested primarily in equity securities, fixed-rate debt securities, and cash and cash equivalents. As discussed in Note 9 to the financial statements in the Form 10-K, when Entergy purchased the Indian Point 3 and FitzPatrick plants in 2000 from NYPA, NYPA retained the decommissioning trusts and the decommissioning liabilities. NYPA and Entergy subsidiaries executed decommissioning agreements, which specified their decommissioning obligations. At the time of the acquisition of the plants Entergy recorded a contract asset that represented an estimate of the present value of the difference between the stipulated contract amount for decommissioning the plants less the decommissioning costs estimated in independent decommissioning cost studies. In August 2016, Entergy entered into a trust transfer agreement with NYPA to transfer the decommissioning trusts and decommissioning liabilities for the Indian Point 3 and FitzPatrick plants to Entergy. The transaction is contingent upon receiving approval from the NRC. As a result of the agreement with NYPA, in the third quarter 2016, Entergy removed the contract asset from its balance sheet, and recorded receivables of $1.5 billion for the beneficial interests in the decommissioning trust funds and recorded asset retirement obligations for the decommissioning liabilities. At September 30, 2016, the fair value of the decommissioning trust funds held by NYPA was $1.5 billion . The fair value is based on the trust statements received from NYPA and is valued by the fund administrator using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value hierarchy. The receivables for the beneficial interests in the decommissioning trust funds are recorded in other deferred debits on the consolidated balance sheet. 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 has recorded an offsetting amount of unrealized gains/(losses) in other deferred credits. Decommissioning trust funds for Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains recorded on the assets in these trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity because these assets are classified as available-for-sale. Unrealized losses (where cost exceeds fair market value) on the assets in these 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. Generally, Entergy records realized gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,380 $1,568 $1 Debt Securities 2,291 94 2 Total $5,671 $1,662 $3 Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2015 Equity Securities $3,195 $1,396 $2 Debt Securities 2,155 41 17 Total $5,350 $1,437 $19 Deferred taxes on unrealized gains/(losses) are recorded in other comprehensive income for the decommissioning trusts which do not meet the criteria for regulatory accounting treatment as described above. Unrealized gains/(losses) above are reported before deferred taxes of $400 million and $342 million as of September 30, 2016 and December 31, 2015 , respectively. The amortized cost of debt securities was $2,199 million as of September 30, 2016 and $2,124 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 3.19% , an average duration of approximately 5.96 years, and an average maturity of approximately 9.39 years. 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 fair value and gross unrealized losses of available-for-sale equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $13 $1 $266 $1 More than 12 months — — 23 1 Total $13 $1 $289 $2 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $54 $2 $1,031 $15 More than 12 months 1 — 61 2 Total $55 $2 $1,092 $17 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $102 $77 1 year - 5 years 812 857 5 years - 10 years 743 704 10 years - 15 years 128 124 15 years - 20 years 62 50 20 years+ 444 343 Total $2,291 $2,155 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $564 million and $539 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $6 million and $13 million , respectively, and gross losses of $1 million and $4 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $1,797 million and $1,488 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $26 million and $58 million , respectively, and gross losses of $6 million and $7 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. Entergy Arkansas Entergy Arkansas holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $504.9 $263.4 $— Debt Securities 318.9 10.8 0.3 Total $823.8 $274.2 $0.3 2015 Equity Securities $467.4 $234.4 $0.2 Debt Securities 303.9 4.1 2.2 Total $771.3 $238.5 $2.4 The amortized cost of debt securities was $308.4 million as of September 30, 2016 and $301.8 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 2.63% , an average duration of approximately 5.21 years, and an average maturity of approximately 5.97 years. 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 equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $0.9 $— $32.5 $0.3 More than 12 months — — — — Total $0.9 $— $32.5 $0.3 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $7.8 $0.2 $111.4 $1.7 More than 12 months — — 18.5 0.5 Total $7.8 $0.2 $129.9 $2.2 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $8.8 $1.8 1 year - 5 years 123.5 145.2 5 years - 10 years 166.1 138.5 10 years - 15 years 9.5 2.4 15 years - 20 years 1.1 2.0 20 years+ 9.9 14.0 Total $318.9 $303.9 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $61.2 million and $44 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $0.4 million and $0.4 million , respectively, and gross losses of $0.04 million and $0.1 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $165 million and $190.8 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $1.6 million and $5.8 million , respectively, and gross losses of $0.3 million and $0.1 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $684.7 $322.9 $— Debt Securities 440.1 21.4 0.4 Total $1,124.8 $344.3 $0.4 2015 Equity Securities $632.4 $283.7 $0.2 Debt Securities 409.9 13.2 2.4 Total $1,042.3 $296.9 $2.6 The amortized cost of debt securities was $419.2 million as of September 30, 2016 and $399.2 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 3.83% , an average duration of approximately 5.72 years, and an average maturity of approximately 11.39 years. 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 equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $2.3 $— $32.5 $0.2 More than 12 months — — 6.5 0.2 Total $2.3 $— $39.0 $0.4 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $9.4 $0.2 $124.0 $2.0 More than 12 months — — 7.4 0.4 Total $9.4 $0.2 $131.4 $2.4 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $25.0 $27.1 1 year - 5 years 102.3 124.0 5 years - 10 years 121.5 114.3 10 years - 15 years 51.0 39.3 15 years - 20 years 31.1 26.5 20 years+ 109.2 78.7 Total $440.1 $409.9 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $54.7 million and $28.4 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $0.4 million and $0.2 million , respectively, and gross losses of $0.1 million and $0.1 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $178.2 million and $93.6 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $3 million and $1.7 million , respectively, and gross losses of $0.2 million and $0.3 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $456.3 $205.5 $0.1 Debt Securities 308.6 6.7 0.3 Total $764.9 $212.2 $0.4 2015 Equity Securities $423.7 $179.2 $0.3 Debt Securities 277.8 2.2 2.3 Total $701.5 $181.4 $2.6 The amortized cost of debt securities was $302.3 million as of September 30, 2016 and $270.7 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 1.79% , an average duration of approximately 5.18 years, and an average maturity of approximately 6.32 years. 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 equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $0.8 $— $81.4 $0.2 More than 12 months — 0.1 1.0 0.1 Total $0.8 $0.1 $82.4 $0.3 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8.3 $0.2 $200.4 $2.2 More than 12 months 0.9 0.1 5.0 0.1 Total $9.2 $0.3 $205.4 $2.3 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $3.0 $2.0 1 year - 5 years 192.6 181.2 5 years - 10 years 76.2 63.0 10 years - 15 years 3.5 4.4 15 years - 20 years 1.5 1.6 20 years+ 31.8 25.6 Total $308.6 $277.8 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $103.5 million and $163.4 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $0.7 million and $2.4 million , respectively, and gross losses of $0.06 million and $0.2 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $392.9 million and $325.4 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $3.2 million and $3.2 million , respectively, and gross losses of $0.4 million and $0.3 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy evaluate 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, 2016 and 2015 . The assessment of whether an investment in an equity security has suffered an other-than-temporary impairment continues to be based on a number of factors including, first, whether Entergy has the ability and intent to hold the investment to recover its value, the duration and severity of any losses, and, then, whether it is expected that the investment will recover its value within a reasonable period of time. 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 did not have any material charges relating to other-than-temporary impairment of certain equity securities for the three and nine months ended September 30, 2016 and 2015 .
Entergy Louisiana [Member]
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) Entergy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The NRC requires Entergy subsidiaries to maintain trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades. The funds are invested primarily in equity securities, fixed-rate debt securities, and cash and cash equivalents. As discussed in Note 9 to the financial statements in the Form 10-K, when Entergy purchased the Indian Point 3 and FitzPatrick plants in 2000 from NYPA, NYPA retained the decommissioning trusts and the decommissioning liabilities. NYPA and Entergy subsidiaries executed decommissioning agreements, which specified their decommissioning obligations. At the time of the acquisition of the plants Entergy recorded a contract asset that represented an estimate of the present value of the difference between the stipulated contract amount for decommissioning the plants less the decommissioning costs estimated in independent decommissioning cost studies. In August 2016, Entergy entered into a trust transfer agreement with NYPA to transfer the decommissioning trusts and decommissioning liabilities for the Indian Point 3 and FitzPatrick plants to Entergy. The transaction is contingent upon receiving approval from the NRC. As a result of the agreement with NYPA, in the third quarter 2016, Entergy removed the contract asset from its balance sheet, and recorded receivables of $1.5 billion for the beneficial interests in the decommissioning trust funds and recorded asset retirement obligations for the decommissioning liabilities. At September 30, 2016, the fair value of the decommissioning trust funds held by NYPA was $1.5 billion . The fair value is based on the trust statements received from NYPA and is valued by the fund administrator using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value hierarchy. The receivables for the beneficial interests in the decommissioning trust funds are recorded in other deferred debits on the consolidated balance sheet. 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 has recorded an offsetting amount of unrealized gains/(losses) in other deferred credits. Decommissioning trust funds for Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains recorded on the assets in these trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity because these assets are classified as available-for-sale. Unrealized losses (where cost exceeds fair market value) on the assets in these 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. Generally, Entergy records realized gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,380 $1,568 $1 Debt Securities 2,291 94 2 Total $5,671 $1,662 $3 Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2015 Equity Securities $3,195 $1,396 $2 Debt Securities 2,155 41 17 Total $5,350 $1,437 $19 Deferred taxes on unrealized gains/(losses) are recorded in other comprehensive income for the decommissioning trusts which do not meet the criteria for regulatory accounting treatment as described above. Unrealized gains/(losses) above are reported before deferred taxes of $400 million and $342 million as of September 30, 2016 and December 31, 2015 , respectively. The amortized cost of debt securities was $2,199 million as of September 30, 2016 and $2,124 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 3.19% , an average duration of approximately 5.96 years, and an average maturity of approximately 9.39 years. 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 fair value and gross unrealized losses of available-for-sale equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $13 $1 $266 $1 More than 12 months — — 23 1 Total $13 $1 $289 $2 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $54 $2 $1,031 $15 More than 12 months 1 — 61 2 Total $55 $2 $1,092 $17 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $102 $77 1 year - 5 years 812 857 5 years - 10 years 743 704 10 years - 15 years 128 124 15 years - 20 years 62 50 20 years+ 444 343 Total $2,291 $2,155 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $564 million and $539 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $6 million and $13 million , respectively, and gross losses of $1 million and $4 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $1,797 million and $1,488 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $26 million and $58 million , respectively, and gross losses of $6 million and $7 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. Entergy Arkansas Entergy Arkansas holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $504.9 $263.4 $— Debt Securities 318.9 10.8 0.3 Total $823.8 $274.2 $0.3 2015 Equity Securities $467.4 $234.4 $0.2 Debt Securities 303.9 4.1 2.2 Total $771.3 $238.5 $2.4 The amortized cost of debt securities was $308.4 million as of September 30, 2016 and $301.8 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 2.63% , an average duration of approximately 5.21 years, and an average maturity of approximately 5.97 years. 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 equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $0.9 $— $32.5 $0.3 More than 12 months — — — — Total $0.9 $— $32.5 $0.3 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $7.8 $0.2 $111.4 $1.7 More than 12 months — — 18.5 0.5 Total $7.8 $0.2 $129.9 $2.2 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $8.8 $1.8 1 year - 5 years 123.5 145.2 5 years - 10 years 166.1 138.5 10 years - 15 years 9.5 2.4 15 years - 20 years 1.1 2.0 20 years+ 9.9 14.0 Total $318.9 $303.9 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $61.2 million and $44 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $0.4 million and $0.4 million , respectively, and gross losses of $0.04 million and $0.1 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $165 million and $190.8 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $1.6 million and $5.8 million , respectively, and gross losses of $0.3 million and $0.1 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $684.7 $322.9 $— Debt Securities 440.1 21.4 0.4 Total $1,124.8 $344.3 $0.4 2015 Equity Securities $632.4 $283.7 $0.2 Debt Securities 409.9 13.2 2.4 Total $1,042.3 $296.9 $2.6 The amortized cost of debt securities was $419.2 million as of September 30, 2016 and $399.2 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 3.83% , an average duration of approximately 5.72 years, and an average maturity of approximately 11.39 years. 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 equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $2.3 $— $32.5 $0.2 More than 12 months — — 6.5 0.2 Total $2.3 $— $39.0 $0.4 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $9.4 $0.2 $124.0 $2.0 More than 12 months — — 7.4 0.4 Total $9.4 $0.2 $131.4 $2.4 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $25.0 $27.1 1 year - 5 years 102.3 124.0 5 years - 10 years 121.5 114.3 10 years - 15 years 51.0 39.3 15 years - 20 years 31.1 26.5 20 years+ 109.2 78.7 Total $440.1 $409.9 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $54.7 million and $28.4 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $0.4 million and $0.2 million , respectively, and gross losses of $0.1 million and $0.1 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $178.2 million and $93.6 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $3 million and $1.7 million , respectively, and gross losses of $0.2 million and $0.3 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $456.3 $205.5 $0.1 Debt Securities 308.6 6.7 0.3 Total $764.9 $212.2 $0.4 2015 Equity Securities $423.7 $179.2 $0.3 Debt Securities 277.8 2.2 2.3 Total $701.5 $181.4 $2.6 The amortized cost of debt securities was $302.3 million as of September 30, 2016 and $270.7 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 1.79% , an average duration of approximately 5.18 years, and an average maturity of approximately 6.32 years. 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 equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $0.8 $— $81.4 $0.2 More than 12 months — 0.1 1.0 0.1 Total $0.8 $0.1 $82.4 $0.3 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8.3 $0.2 $200.4 $2.2 More than 12 months 0.9 0.1 5.0 0.1 Total $9.2 $0.3 $205.4 $2.3 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $3.0 $2.0 1 year - 5 years 192.6 181.2 5 years - 10 years 76.2 63.0 10 years - 15 years 3.5 4.4 15 years - 20 years 1.5 1.6 20 years+ 31.8 25.6 Total $308.6 $277.8 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $103.5 million and $163.4 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $0.7 million and $2.4 million , respectively, and gross losses of $0.06 million and $0.2 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $392.9 million and $325.4 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $3.2 million and $3.2 million , respectively, and gross losses of $0.4 million and $0.3 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy evaluate 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, 2016 and 2015 . The assessment of whether an investment in an equity security has suffered an other-than-temporary impairment continues to be based on a number of factors including, first, whether Entergy has the ability and intent to hold the investment to recover its value, the duration and severity of any losses, and, then, whether it is expected that the investment will recover its value within a reasonable period of time. 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 did not have any material charges relating to other-than-temporary impairment of certain equity securities for the three and nine months ended September 30, 2016 and 2015 .
System Energy [Member]
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) Entergy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The NRC requires Entergy subsidiaries to maintain trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades. The funds are invested primarily in equity securities, fixed-rate debt securities, and cash and cash equivalents. As discussed in Note 9 to the financial statements in the Form 10-K, when Entergy purchased the Indian Point 3 and FitzPatrick plants in 2000 from NYPA, NYPA retained the decommissioning trusts and the decommissioning liabilities. NYPA and Entergy subsidiaries executed decommissioning agreements, which specified their decommissioning obligations. At the time of the acquisition of the plants Entergy recorded a contract asset that represented an estimate of the present value of the difference between the stipulated contract amount for decommissioning the plants less the decommissioning costs estimated in independent decommissioning cost studies. In August 2016, Entergy entered into a trust transfer agreement with NYPA to transfer the decommissioning trusts and decommissioning liabilities for the Indian Point 3 and FitzPatrick plants to Entergy. The transaction is contingent upon receiving approval from the NRC. As a result of the agreement with NYPA, in the third quarter 2016, Entergy removed the contract asset from its balance sheet, and recorded receivables of $1.5 billion for the beneficial interests in the decommissioning trust funds and recorded asset retirement obligations for the decommissioning liabilities. At September 30, 2016, the fair value of the decommissioning trust funds held by NYPA was $1.5 billion . The fair value is based on the trust statements received from NYPA and is valued by the fund administrator using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value hierarchy. The receivables for the beneficial interests in the decommissioning trust funds are recorded in other deferred debits on the consolidated balance sheet. 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 has recorded an offsetting amount of unrealized gains/(losses) in other deferred credits. Decommissioning trust funds for Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains recorded on the assets in these trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity because these assets are classified as available-for-sale. Unrealized losses (where cost exceeds fair market value) on the assets in these 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. Generally, Entergy records realized gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,380 $1,568 $1 Debt Securities 2,291 94 2 Total $5,671 $1,662 $3 Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2015 Equity Securities $3,195 $1,396 $2 Debt Securities 2,155 41 17 Total $5,350 $1,437 $19 Deferred taxes on unrealized gains/(losses) are recorded in other comprehensive income for the decommissioning trusts which do not meet the criteria for regulatory accounting treatment as described above. Unrealized gains/(losses) above are reported before deferred taxes of $400 million and $342 million as of September 30, 2016 and December 31, 2015 , respectively. The amortized cost of debt securities was $2,199 million as of September 30, 2016 and $2,124 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 3.19% , an average duration of approximately 5.96 years, and an average maturity of approximately 9.39 years. 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 fair value and gross unrealized losses of available-for-sale equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $13 $1 $266 $1 More than 12 months — — 23 1 Total $13 $1 $289 $2 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $54 $2 $1,031 $15 More than 12 months 1 — 61 2 Total $55 $2 $1,092 $17 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $102 $77 1 year - 5 years 812 857 5 years - 10 years 743 704 10 years - 15 years 128 124 15 years - 20 years 62 50 20 years+ 444 343 Total $2,291 $2,155 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $564 million and $539 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $6 million and $13 million , respectively, and gross losses of $1 million and $4 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $1,797 million and $1,488 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $26 million and $58 million , respectively, and gross losses of $6 million and $7 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. Entergy Arkansas Entergy Arkansas holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $504.9 $263.4 $— Debt Securities 318.9 10.8 0.3 Total $823.8 $274.2 $0.3 2015 Equity Securities $467.4 $234.4 $0.2 Debt Securities 303.9 4.1 2.2 Total $771.3 $238.5 $2.4 The amortized cost of debt securities was $308.4 million as of September 30, 2016 and $301.8 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 2.63% , an average duration of approximately 5.21 years, and an average maturity of approximately 5.97 years. 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 equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $0.9 $— $32.5 $0.3 More than 12 months — — — — Total $0.9 $— $32.5 $0.3 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $7.8 $0.2 $111.4 $1.7 More than 12 months — — 18.5 0.5 Total $7.8 $0.2 $129.9 $2.2 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $8.8 $1.8 1 year - 5 years 123.5 145.2 5 years - 10 years 166.1 138.5 10 years - 15 years 9.5 2.4 15 years - 20 years 1.1 2.0 20 years+ 9.9 14.0 Total $318.9 $303.9 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $61.2 million and $44 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $0.4 million and $0.4 million , respectively, and gross losses of $0.04 million and $0.1 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $165 million and $190.8 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $1.6 million and $5.8 million , respectively, and gross losses of $0.3 million and $0.1 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $684.7 $322.9 $— Debt Securities 440.1 21.4 0.4 Total $1,124.8 $344.3 $0.4 2015 Equity Securities $632.4 $283.7 $0.2 Debt Securities 409.9 13.2 2.4 Total $1,042.3 $296.9 $2.6 The amortized cost of debt securities was $419.2 million as of September 30, 2016 and $399.2 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 3.83% , an average duration of approximately 5.72 years, and an average maturity of approximately 11.39 years. 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 equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $2.3 $— $32.5 $0.2 More than 12 months — — 6.5 0.2 Total $2.3 $— $39.0 $0.4 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $9.4 $0.2 $124.0 $2.0 More than 12 months — — 7.4 0.4 Total $9.4 $0.2 $131.4 $2.4 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $25.0 $27.1 1 year - 5 years 102.3 124.0 5 years - 10 years 121.5 114.3 10 years - 15 years 51.0 39.3 15 years - 20 years 31.1 26.5 20 years+ 109.2 78.7 Total $440.1 $409.9 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $54.7 million and $28.4 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $0.4 million and $0.2 million , respectively, and gross losses of $0.1 million and $0.1 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $178.2 million and $93.6 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $3 million and $1.7 million , respectively, and gross losses of $0.2 million and $0.3 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $456.3 $205.5 $0.1 Debt Securities 308.6 6.7 0.3 Total $764.9 $212.2 $0.4 2015 Equity Securities $423.7 $179.2 $0.3 Debt Securities 277.8 2.2 2.3 Total $701.5 $181.4 $2.6 The amortized cost of debt securities was $302.3 million as of September 30, 2016 and $270.7 million as of December 31, 2015 . As of September 30, 2016 , the debt securities have an average coupon rate of approximately 1.79% , an average duration of approximately 5.18 years, and an average maturity of approximately 6.32 years. 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 equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $0.8 $— $81.4 $0.2 More than 12 months — 0.1 1.0 0.1 Total $0.8 $0.1 $82.4 $0.3 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8.3 $0.2 $200.4 $2.2 More than 12 months 0.9 0.1 5.0 0.1 Total $9.2 $0.3 $205.4 $2.3 The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $3.0 $2.0 1 year - 5 years 192.6 181.2 5 years - 10 years 76.2 63.0 10 years - 15 years 3.5 4.4 15 years - 20 years 1.5 1.6 20 years+ 31.8 25.6 Total $308.6 $277.8 During the three months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $103.5 million and $163.4 million , respectively. During the three months ended September 30, 2016 and 2015 , gross gains of $0.7 million and $2.4 million , respectively, and gross losses of $0.06 million and $0.2 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $392.9 million and $325.4 million , respectively. During the nine months ended September 30, 2016 and 2015 , gross gains of $3.2 million and $3.2 million , respectively, and gross losses of $0.4 million and $0.3 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy evaluate 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, 2016 and 2015 . The assessment of whether an investment in an equity security has suffered an other-than-temporary impairment continues to be based on a number of factors including, first, whether Entergy has the ability and intent to hold the investment to recover its value, the duration and severity of any losses, and, then, whether it is expected that the investment will recover its value within a reasonable period of time. 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 did not have any material charges relating to other-than-temporary impairment of certain equity securities for the three and nine months ended September 30, 2016 and 2015 .

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2016
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Litigation ,” “ 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 proceedings, income tax audits, and other income tax matters involving Entergy. The following are updates to that discussion. 2010-2011 IRS Audit The IRS has completed its examination of the 2010 and 2011 tax years and issued its 2010-2011 Revenue Agent Report (RAR) in June 2016. Entergy has agreed to all proposed adjustments contained in the RAR. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits as follows: • Entergy and the IRS agreed that $148.6 million of the proceeds received by Entergy Louisiana in 2010 from the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, for the financing of Hurricane Gustav and Hurricane Ike storm costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Louisiana Act 55) were not taxable. Because the treatment of the financing is settled, Entergy recognized previously unrecognized tax benefits totaling $63.5 million , of which Entergy Louisiana recorded $61.6 million . Entergy Louisiana also accrued a regulatory liability of $16.1 million ( $9.9 million net-of-tax) in accordance with the terms of Entergy Louisiana’s previous settlement agreement approved by the LPSC regarding Entergy Louisiana’s obligation to pay to customers savings associated with the Act 55 financing. • Entergy and the IRS agreed upon the tax treatment of Entergy Louisiana’s regulatory liability related to the Vidalia purchased power agreement. As a result, Entergy Louisiana recognized a previously unrecognized tax benefit of $74.5 million . The settlement of the above-described items, along with other minor recorded adjustments, decreased Entergy Louisiana’s balance of unrecognized tax benefits from $796.9 million as of December 31, 2015 to $564.7 million as of June 30, 2016, net of carryovers for losses and credits. The unrecognized tax benefits were settled primarily through utilization of net operating loss carryovers. Other Tax Matters Entergy made a tax election to treat its subsidiary that owns one of the Entergy Wholesale Commodities nuclear power plants as a corporation for federal income tax purposes. This resulted in a constructive contribution of all the assets and liabilities associated with the plant to a new subsidiary corporation for federal income tax purposes, and generated both permanent and temporary differences under the income tax accounting standards. The constructive contribution required Entergy to recognize the plant’s nuclear decommissioning liability for income tax purposes resulting in permanent differences. The accrual of the nuclear decommissioning liability required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiary. Recognition of the gain and the increase in tax basis of the assets represents a temporary difference. The permanent difference reduced income tax expense, net of unrecognized tax benefits, by $238 million .
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 Litigation ,” “ 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 proceedings, income tax audits, and other income tax matters involving Entergy. The following are updates to that discussion. 2010-2011 IRS Audit The IRS has completed its examination of the 2010 and 2011 tax years and issued its 2010-2011 Revenue Agent Report (RAR) in June 2016. Entergy has agreed to all proposed adjustments contained in the RAR. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits as follows: • Entergy and the IRS agreed that $148.6 million of the proceeds received by Entergy Louisiana in 2010 from the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, for the financing of Hurricane Gustav and Hurricane Ike storm costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Louisiana Act 55) were not taxable. Because the treatment of the financing is settled, Entergy recognized previously unrecognized tax benefits totaling $63.5 million , of which Entergy Louisiana recorded $61.6 million . Entergy Louisiana also accrued a regulatory liability of $16.1 million ( $9.9 million net-of-tax) in accordance with the terms of Entergy Louisiana’s previous settlement agreement approved by the LPSC regarding Entergy Louisiana’s obligation to pay to customers savings associated with the Act 55 financing. • Entergy and the IRS agreed upon the tax treatment of Entergy Louisiana’s regulatory liability related to the Vidalia purchased power agreement. As a result, Entergy Louisiana recognized a previously unrecognized tax benefit of $74.5 million . The settlement of the above-described items, along with other minor recorded adjustments, decreased Entergy Louisiana’s balance of unrecognized tax benefits from $796.9 million as of December 31, 2015 to $564.7 million as of June 30, 2016, net of carryovers for losses and credits. The unrecognized tax benefits were settled primarily through utilization of net operating loss carryovers. Other Tax Matters Entergy made a tax election to treat its subsidiary that owns one of the Entergy Wholesale Commodities nuclear power plants as a corporation for federal income tax purposes. This resulted in a constructive contribution of all the assets and liabilities associated with the plant to a new subsidiary corporation for federal income tax purposes, and generated both permanent and temporary differences under the income tax accounting standards. The constructive contribution required Entergy to recognize the plant’s nuclear decommissioning liability for income tax purposes resulting in permanent differences. The accrual of the nuclear decommissioning liability required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiary. Recognition of the gain and the increase in tax basis of the assets represents a temporary difference. The permanent difference reduced income tax expense, net of unrecognized tax benefits, by $238 million .
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 Litigation ,” “ 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 proceedings, income tax audits, and other income tax matters involving Entergy. The following are updates to that discussion. 2010-2011 IRS Audit The IRS has completed its examination of the 2010 and 2011 tax years and issued its 2010-2011 Revenue Agent Report (RAR) in June 2016. Entergy has agreed to all proposed adjustments contained in the RAR. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits as follows: • Entergy and the IRS agreed that $148.6 million of the proceeds received by Entergy Louisiana in 2010 from the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, for the financing of Hurricane Gustav and Hurricane Ike storm costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Louisiana Act 55) were not taxable. Because the treatment of the financing is settled, Entergy recognized previously unrecognized tax benefits totaling $63.5 million , of which Entergy Louisiana recorded $61.6 million . Entergy Louisiana also accrued a regulatory liability of $16.1 million ( $9.9 million net-of-tax) in accordance with the terms of Entergy Louisiana’s previous settlement agreement approved by the LPSC regarding Entergy Louisiana’s obligation to pay to customers savings associated with the Act 55 financing. • Entergy and the IRS agreed upon the tax treatment of Entergy Louisiana’s regulatory liability related to the Vidalia purchased power agreement. As a result, Entergy Louisiana recognized a previously unrecognized tax benefit of $74.5 million . The settlement of the above-described items, along with other minor recorded adjustments, decreased Entergy Louisiana’s balance of unrecognized tax benefits from $796.9 million as of December 31, 2015 to $564.7 million as of June 30, 2016, net of carryovers for losses and credits. The unrecognized tax benefits were settled primarily through utilization of net operating loss carryovers. Other Tax Matters Entergy made a tax election to treat its subsidiary that owns one of the Entergy Wholesale Commodities nuclear power plants as a corporation for federal income tax purposes. This resulted in a constructive contribution of all the assets and liabilities associated with the plant to a new subsidiary corporation for federal income tax purposes, and generated both permanent and temporary differences under the income tax accounting standards. The constructive contribution required Entergy to recognize the plant’s nuclear decommissioning liability for income tax purposes resulting in permanent differences. The accrual of the nuclear decommissioning liability required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiary. Recognition of the gain and the increase in tax basis of the assets represents a temporary difference. The permanent difference reduced income tax expense, net of unrecognized tax benefits, by $238 million .
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 Litigation ,” “ 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 proceedings, income tax audits, and other income tax matters involving Entergy. The following are updates to that discussion. 2010-2011 IRS Audit The IRS has completed its examination of the 2010 and 2011 tax years and issued its 2010-2011 Revenue Agent Report (RAR) in June 2016. Entergy has agreed to all proposed adjustments contained in the RAR. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits as follows: • Entergy and the IRS agreed that $148.6 million of the proceeds received by Entergy Louisiana in 2010 from the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, for the financing of Hurricane Gustav and Hurricane Ike storm costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Louisiana Act 55) were not taxable. Because the treatment of the financing is settled, Entergy recognized previously unrecognized tax benefits totaling $63.5 million , of which Entergy Louisiana recorded $61.6 million . Entergy Louisiana also accrued a regulatory liability of $16.1 million ( $9.9 million net-of-tax) in accordance with the terms of Entergy Louisiana’s previous settlement agreement approved by the LPSC regarding Entergy Louisiana’s obligation to pay to customers savings associated with the Act 55 financing. • Entergy and the IRS agreed upon the tax treatment of Entergy Louisiana’s regulatory liability related to the Vidalia purchased power agreement. As a result, Entergy Louisiana recognized a previously unrecognized tax benefit of $74.5 million . The settlement of the above-described items, along with other minor recorded adjustments, decreased Entergy Louisiana’s balance of unrecognized tax benefits from $796.9 million as of December 31, 2015 to $564.7 million as of June 30, 2016, net of carryovers for losses and credits. The unrecognized tax benefits were settled primarily through utilization of net operating loss carryovers. Other Tax Matters Entergy made a tax election to treat its subsidiary that owns one of the Entergy Wholesale Commodities nuclear power plants as a corporation for federal income tax purposes. This resulted in a constructive contribution of all the assets and liabilities associated with the plant to a new subsidiary corporation for federal income tax purposes, and generated both permanent and temporary differences under the income tax accounting standards. The constructive contribution required Entergy to recognize the plant’s nuclear decommissioning liability for income tax purposes resulting in permanent differences. The accrual of the nuclear decommissioning liability required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiary. Recognition of the gain and the increase in tax basis of the assets represents a temporary difference. The permanent difference reduced income tax expense, net of unrecognized tax benefits, by $238 million .
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 Litigation ,” “ 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 proceedings, income tax audits, and other income tax matters involving Entergy. The following are updates to that discussion. 2010-2011 IRS Audit The IRS has completed its examination of the 2010 and 2011 tax years and issued its 2010-2011 Revenue Agent Report (RAR) in June 2016. Entergy has agreed to all proposed adjustments contained in the RAR. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits as follows: • Entergy and the IRS agreed that $148.6 million of the proceeds received by Entergy Louisiana in 2010 from the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, for the financing of Hurricane Gustav and Hurricane Ike storm costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Louisiana Act 55) were not taxable. Because the treatment of the financing is settled, Entergy recognized previously unrecognized tax benefits totaling $63.5 million , of which Entergy Louisiana recorded $61.6 million . Entergy Louisiana also accrued a regulatory liability of $16.1 million ( $9.9 million net-of-tax) in accordance with the terms of Entergy Louisiana’s previous settlement agreement approved by the LPSC regarding Entergy Louisiana’s obligation to pay to customers savings associated with the Act 55 financing. • Entergy and the IRS agreed upon the tax treatment of Entergy Louisiana’s regulatory liability related to the Vidalia purchased power agreement. As a result, Entergy Louisiana recognized a previously unrecognized tax benefit of $74.5 million . The settlement of the above-described items, along with other minor recorded adjustments, decreased Entergy Louisiana’s balance of unrecognized tax benefits from $796.9 million as of December 31, 2015 to $564.7 million as of June 30, 2016, net of carryovers for losses and credits. The unrecognized tax benefits were settled primarily through utilization of net operating loss carryovers. Other Tax Matters Entergy made a tax election to treat its subsidiary that owns one of the Entergy Wholesale Commodities nuclear power plants as a corporation for federal income tax purposes. This resulted in a constructive contribution of all the assets and liabilities associated with the plant to a new subsidiary corporation for federal income tax purposes, and generated both permanent and temporary differences under the income tax accounting standards. The constructive contribution required Entergy to recognize the plant’s nuclear decommissioning liability for income tax purposes resulting in permanent differences. The accrual of the nuclear decommissioning liability required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiary. Recognition of the gain and the increase in tax basis of the assets represents a temporary difference. The permanent difference reduced income tax expense, net of unrecognized tax benefits, by $238 million .
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 Litigation ,” “ 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 proceedings, income tax audits, and other income tax matters involving Entergy. The following are updates to that discussion. 2010-2011 IRS Audit The IRS has completed its examination of the 2010 and 2011 tax years and issued its 2010-2011 Revenue Agent Report (RAR) in June 2016. Entergy has agreed to all proposed adjustments contained in the RAR. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits as follows: • Entergy and the IRS agreed that $148.6 million of the proceeds received by Entergy Louisiana in 2010 from the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, for the financing of Hurricane Gustav and Hurricane Ike storm costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Louisiana Act 55) were not taxable. Because the treatment of the financing is settled, Entergy recognized previously unrecognized tax benefits totaling $63.5 million , of which Entergy Louisiana recorded $61.6 million . Entergy Louisiana also accrued a regulatory liability of $16.1 million ( $9.9 million net-of-tax) in accordance with the terms of Entergy Louisiana’s previous settlement agreement approved by the LPSC regarding Entergy Louisiana’s obligation to pay to customers savings associated with the Act 55 financing. • Entergy and the IRS agreed upon the tax treatment of Entergy Louisiana’s regulatory liability related to the Vidalia purchased power agreement. As a result, Entergy Louisiana recognized a previously unrecognized tax benefit of $74.5 million . The settlement of the above-described items, along with other minor recorded adjustments, decreased Entergy Louisiana’s balance of unrecognized tax benefits from $796.9 million as of December 31, 2015 to $564.7 million as of June 30, 2016, net of carryovers for losses and credits. The unrecognized tax benefits were settled primarily through utilization of net operating loss carryovers. Other Tax Matters Entergy made a tax election to treat its subsidiary that owns one of the Entergy Wholesale Commodities nuclear power plants as a corporation for federal income tax purposes. This resulted in a constructive contribution of all the assets and liabilities associated with the plant to a new subsidiary corporation for federal income tax purposes, and generated both permanent and temporary differences under the income tax accounting standards. The constructive contribution required Entergy to recognize the plant’s nuclear decommissioning liability for income tax purposes resulting in permanent differences. The accrual of the nuclear decommissioning liability required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiary. Recognition of the gain and the increase in tax basis of the assets represents a temporary difference. The permanent difference reduced income tax expense, net of unrecognized tax benefits, by $238 million .
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 Litigation ,” “ 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 proceedings, income tax audits, and other income tax matters involving Entergy. The following are updates to that discussion. 2010-2011 IRS Audit The IRS has completed its examination of the 2010 and 2011 tax years and issued its 2010-2011 Revenue Agent Report (RAR) in June 2016. Entergy has agreed to all proposed adjustments contained in the RAR. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits as follows: • Entergy and the IRS agreed that $148.6 million of the proceeds received by Entergy Louisiana in 2010 from the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, for the financing of Hurricane Gustav and Hurricane Ike storm costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Louisiana Act 55) were not taxable. Because the treatment of the financing is settled, Entergy recognized previously unrecognized tax benefits totaling $63.5 million , of which Entergy Louisiana recorded $61.6 million . Entergy Louisiana also accrued a regulatory liability of $16.1 million ( $9.9 million net-of-tax) in accordance with the terms of Entergy Louisiana’s previous settlement agreement approved by the LPSC regarding Entergy Louisiana’s obligation to pay to customers savings associated with the Act 55 financing. • Entergy and the IRS agreed upon the tax treatment of Entergy Louisiana’s regulatory liability related to the Vidalia purchased power agreement. As a result, Entergy Louisiana recognized a previously unrecognized tax benefit of $74.5 million . The settlement of the above-described items, along with other minor recorded adjustments, decreased Entergy Louisiana’s balance of unrecognized tax benefits from $796.9 million as of December 31, 2015 to $564.7 million as of June 30, 2016, net of carryovers for losses and credits. The unrecognized tax benefits were settled primarily through utilization of net operating loss carryovers. Other Tax Matters Entergy made a tax election to treat its subsidiary that owns one of the Entergy Wholesale Commodities nuclear power plants as a corporation for federal income tax purposes. This resulted in a constructive contribution of all the assets and liabilities associated with the plant to a new subsidiary corporation for federal income tax purposes, and generated both permanent and temporary differences under the income tax accounting standards. The constructive contribution required Entergy to recognize the plant’s nuclear decommissioning liability for income tax purposes resulting in permanent differences. The accrual of the nuclear decommissioning liability required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiary. Recognition of the gain and the increase in tax basis of the assets represents a temporary difference. The permanent difference reduced income tax expense, net of unrecognized tax benefits, by $238 million .

Property, Plant, And Equipment

Property, Plant, And Equipment	9 Months Ended
	Sep. 30, 2016
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, 2016 are $175.8 million for Entergy, $21.7 million for Entergy Arkansas, $75.5 million for Entergy Louisiana, $4.5 million for Entergy Mississippi, $1 million for Entergy New Orleans, $8 million for Entergy Texas, and $12.7 million for System Energy. Construction expenditures included in accounts payable at December 31, 2015 are $234 million for Entergy, $43 million for Entergy Arkansas, $68.6 million for Entergy Louisiana, $11.4 million for Entergy Mississippi, $1.5 million for Entergy New Orleans, $33.1 million for Entergy Texas, and $6.8 million for System Energy. Waterford 3 Transaction See Note 10 to the financial statements in the Form 10-K for a discussion of the Waterford 3 lease obligation. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana will continue to make payments on the lessor debt that remains outstanding. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt will be equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017.
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, 2016 are $175.8 million for Entergy, $21.7 million for Entergy Arkansas, $75.5 million for Entergy Louisiana, $4.5 million for Entergy Mississippi, $1 million for Entergy New Orleans, $8 million for Entergy Texas, and $12.7 million for System Energy. Construction expenditures included in accounts payable at December 31, 2015 are $234 million for Entergy, $43 million for Entergy Arkansas, $68.6 million for Entergy Louisiana, $11.4 million for Entergy Mississippi, $1.5 million for Entergy New Orleans, $33.1 million for Entergy Texas, and $6.8 million for System Energy. Waterford 3 Transaction See Note 10 to the financial statements in the Form 10-K for a discussion of the Waterford 3 lease obligation. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana will continue to make payments on the lessor debt that remains outstanding. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt will be equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017.
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, 2016 are $175.8 million for Entergy, $21.7 million for Entergy Arkansas, $75.5 million for Entergy Louisiana, $4.5 million for Entergy Mississippi, $1 million for Entergy New Orleans, $8 million for Entergy Texas, and $12.7 million for System Energy. Construction expenditures included in accounts payable at December 31, 2015 are $234 million for Entergy, $43 million for Entergy Arkansas, $68.6 million for Entergy Louisiana, $11.4 million for Entergy Mississippi, $1.5 million for Entergy New Orleans, $33.1 million for Entergy Texas, and $6.8 million for System Energy. Waterford 3 Transaction See Note 10 to the financial statements in the Form 10-K for a discussion of the Waterford 3 lease obligation. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana will continue to make payments on the lessor debt that remains outstanding. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt will be equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017.
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, 2016 are $175.8 million for Entergy, $21.7 million for Entergy Arkansas, $75.5 million for Entergy Louisiana, $4.5 million for Entergy Mississippi, $1 million for Entergy New Orleans, $8 million for Entergy Texas, and $12.7 million for System Energy. Construction expenditures included in accounts payable at December 31, 2015 are $234 million for Entergy, $43 million for Entergy Arkansas, $68.6 million for Entergy Louisiana, $11.4 million for Entergy Mississippi, $1.5 million for Entergy New Orleans, $33.1 million for Entergy Texas, and $6.8 million for System Energy. Waterford 3 Transaction See Note 10 to the financial statements in the Form 10-K for a discussion of the Waterford 3 lease obligation. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana will continue to make payments on the lessor debt that remains outstanding. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt will be equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017.
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, 2016 are $175.8 million for Entergy, $21.7 million for Entergy Arkansas, $75.5 million for Entergy Louisiana, $4.5 million for Entergy Mississippi, $1 million for Entergy New Orleans, $8 million for Entergy Texas, and $12.7 million for System Energy. Construction expenditures included in accounts payable at December 31, 2015 are $234 million for Entergy, $43 million for Entergy Arkansas, $68.6 million for Entergy Louisiana, $11.4 million for Entergy Mississippi, $1.5 million for Entergy New Orleans, $33.1 million for Entergy Texas, and $6.8 million for System Energy. Waterford 3 Transaction See Note 10 to the financial statements in the Form 10-K for a discussion of the Waterford 3 lease obligation. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana will continue to make payments on the lessor debt that remains outstanding. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt will be equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017.
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, 2016 are $175.8 million for Entergy, $21.7 million for Entergy Arkansas, $75.5 million for Entergy Louisiana, $4.5 million for Entergy Mississippi, $1 million for Entergy New Orleans, $8 million for Entergy Texas, and $12.7 million for System Energy. Construction expenditures included in accounts payable at December 31, 2015 are $234 million for Entergy, $43 million for Entergy Arkansas, $68.6 million for Entergy Louisiana, $11.4 million for Entergy Mississippi, $1.5 million for Entergy New Orleans, $33.1 million for Entergy Texas, and $6.8 million for System Energy. Waterford 3 Transaction See Note 10 to the financial statements in the Form 10-K for a discussion of the Waterford 3 lease obligation. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana will continue to make payments on the lessor debt that remains outstanding. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt will be equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017.
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, 2016 are $175.8 million for Entergy, $21.7 million for Entergy Arkansas, $75.5 million for Entergy Louisiana, $4.5 million for Entergy Mississippi, $1 million for Entergy New Orleans, $8 million for Entergy Texas, and $12.7 million for System Energy. Construction expenditures included in accounts payable at December 31, 2015 are $234 million for Entergy, $43 million for Entergy Arkansas, $68.6 million for Entergy Louisiana, $11.4 million for Entergy Mississippi, $1.5 million for Entergy New Orleans, $33.1 million for Entergy Texas, and $6.8 million for System Energy. Waterford 3 Transaction See Note 10 to the financial statements in the Form 10-K for a discussion of the Waterford 3 lease obligation. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana will continue to make payments on the lessor debt that remains outstanding. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt will be equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017.

Variable Interest Entities

Variable Interest Entities	9 Months Ended
	Sep. 30, 2016
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 18 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. Entergy Louisiana was considered to hold a variable interest in the lessor from which it leased an undivided interest representing approximately 9.3% of the Waterford 3 nuclear plant. After Entergy Louisiana acquired a beneficial interest in the leased assets in March 2016, however, the lessor was no longer considered a variable interest entity. Entergy Louisiana made payments on its lease, including interest, of $7.8 million in the three months ended September 30, 2016 and $7.8 million in the three months ended September 30, 2015 . Entergy Louisiana made payments on its lease, including interest, of $16.9 million in the nine months ended September 30, 2016 and $28.8 million in the nine months ended September 30, 2015 . See Note 11 to the financial statements herein for a discussion of Entergy Louisiana’s purchase of a beneficial interest in the Waterford 3 leased assets. 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, 2016 and $14.6 million in the three months ended September 30, 2015 . System Energy made payments on its lease, including interest, of $17.2 million in the nine months ended September 30, 2016 and $52.3 million in the nine months ended September 30, 2015 .
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 18 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. Entergy Louisiana was considered to hold a variable interest in the lessor from which it leased an undivided interest representing approximately 9.3% of the Waterford 3 nuclear plant. After Entergy Louisiana acquired a beneficial interest in the leased assets in March 2016, however, the lessor was no longer considered a variable interest entity. Entergy Louisiana made payments on its lease, including interest, of $7.8 million in the three months ended September 30, 2016 and $7.8 million in the three months ended September 30, 2015 . Entergy Louisiana made payments on its lease, including interest, of $16.9 million in the nine months ended September 30, 2016 and $28.8 million in the nine months ended September 30, 2015 . See Note 11 to the financial statements herein for a discussion of Entergy Louisiana’s purchase of a beneficial interest in the Waterford 3 leased assets. 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, 2016 and $14.6 million in the three months ended September 30, 2015 . System Energy made payments on its lease, including interest, of $17.2 million in the nine months ended September 30, 2016 and $52.3 million in the nine months ended September 30, 2015 .
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 18 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. Entergy Louisiana was considered to hold a variable interest in the lessor from which it leased an undivided interest representing approximately 9.3% of the Waterford 3 nuclear plant. After Entergy Louisiana acquired a beneficial interest in the leased assets in March 2016, however, the lessor was no longer considered a variable interest entity. Entergy Louisiana made payments on its lease, including interest, of $7.8 million in the three months ended September 30, 2016 and $7.8 million in the three months ended September 30, 2015 . Entergy Louisiana made payments on its lease, including interest, of $16.9 million in the nine months ended September 30, 2016 and $28.8 million in the nine months ended September 30, 2015 . See Note 11 to the financial statements herein for a discussion of Entergy Louisiana’s purchase of a beneficial interest in the Waterford 3 leased assets. 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, 2016 and $14.6 million in the three months ended September 30, 2015 . System Energy made payments on its lease, including interest, of $17.2 million in the nine months ended September 30, 2016 and $52.3 million in the nine months ended September 30, 2015 .
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 18 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. Entergy Louisiana was considered to hold a variable interest in the lessor from which it leased an undivided interest representing approximately 9.3% of the Waterford 3 nuclear plant. After Entergy Louisiana acquired a beneficial interest in the leased assets in March 2016, however, the lessor was no longer considered a variable interest entity. Entergy Louisiana made payments on its lease, including interest, of $7.8 million in the three months ended September 30, 2016 and $7.8 million in the three months ended September 30, 2015 . Entergy Louisiana made payments on its lease, including interest, of $16.9 million in the nine months ended September 30, 2016 and $28.8 million in the nine months ended September 30, 2015 . See Note 11 to the financial statements herein for a discussion of Entergy Louisiana’s purchase of a beneficial interest in the Waterford 3 leased assets. 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, 2016 and $14.6 million in the three months ended September 30, 2015 . System Energy made payments on its lease, including interest, of $17.2 million in the nine months ended September 30, 2016 and $52.3 million in the nine months ended September 30, 2015 .
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 18 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. Entergy Louisiana was considered to hold a variable interest in the lessor from which it leased an undivided interest representing approximately 9.3% of the Waterford 3 nuclear plant. After Entergy Louisiana acquired a beneficial interest in the leased assets in March 2016, however, the lessor was no longer considered a variable interest entity. Entergy Louisiana made payments on its lease, including interest, of $7.8 million in the three months ended September 30, 2016 and $7.8 million in the three months ended September 30, 2015 . Entergy Louisiana made payments on its lease, including interest, of $16.9 million in the nine months ended September 30, 2016 and $28.8 million in the nine months ended September 30, 2015 . See Note 11 to the financial statements herein for a discussion of Entergy Louisiana’s purchase of a beneficial interest in the Waterford 3 leased assets. 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, 2016 and $14.6 million in the three months ended September 30, 2015 . System Energy made payments on its lease, including interest, of $17.2 million in the nine months ended September 30, 2016 and $52.3 million in the nine months ended September 30, 2015 .
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 18 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. Entergy Louisiana was considered to hold a variable interest in the lessor from which it leased an undivided interest representing approximately 9.3% of the Waterford 3 nuclear plant. After Entergy Louisiana acquired a beneficial interest in the leased assets in March 2016, however, the lessor was no longer considered a variable interest entity. Entergy Louisiana made payments on its lease, including interest, of $7.8 million in the three months ended September 30, 2016 and $7.8 million in the three months ended September 30, 2015 . Entergy Louisiana made payments on its lease, including interest, of $16.9 million in the nine months ended September 30, 2016 and $28.8 million in the nine months ended September 30, 2015 . See Note 11 to the financial statements herein for a discussion of Entergy Louisiana’s purchase of a beneficial interest in the Waterford 3 leased assets. 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, 2016 and $14.6 million in the three months ended September 30, 2015 . System Energy made payments on its lease, including interest, of $17.2 million in the nine months ended September 30, 2016 and $52.3 million in the nine months ended September 30, 2015 .
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 18 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. Entergy Louisiana was considered to hold a variable interest in the lessor from which it leased an undivided interest representing approximately 9.3% of the Waterford 3 nuclear plant. After Entergy Louisiana acquired a beneficial interest in the leased assets in March 2016, however, the lessor was no longer considered a variable interest entity. Entergy Louisiana made payments on its lease, including interest, of $7.8 million in the three months ended September 30, 2016 and $7.8 million in the three months ended September 30, 2015 . Entergy Louisiana made payments on its lease, including interest, of $16.9 million in the nine months ended September 30, 2016 and $28.8 million in the nine months ended September 30, 2015 . See Note 11 to the financial statements herein for a discussion of Entergy Louisiana’s purchase of a beneficial interest in the Waterford 3 leased assets. 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, 2016 and $14.6 million in the three months ended September 30, 2015 . System Energy made payments on its lease, including interest, of $17.2 million in the nine months ended September 30, 2016 and $52.3 million in the nine months ended September 30, 2015 .

Acquisitions Acquisitions

Acquisitions Acquisitions	9 Months Ended
	Sep. 30, 2016
Business Acquisition [Line Items]
Acquisitions [Text Block]	ACQUISITIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans) In March 2016, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans purchased the Union Power Station, a 1,980 MW (summer rating) power generation facility located near El Dorado, Arkansas, from Union Power Partners, L.P. The Union Power Station consists of four natural gas-fired, combined-cycle gas turbine power blocks, each rated at 495 MW (summer rating). Entergy Louisiana purchased two of the power blocks and a 50% undivided ownership interest in certain assets related to the facility, and Entergy Arkansas and Entergy New Orleans each purchased one power block and a 25% undivided ownership interest in such related assets. The aggregate purchase price for the Union Power Station was approximately $949 million (approximately $237 million for each power block and associated assets)
Entergy Arkansas [Member]
Business Acquisition [Line Items]
Acquisitions [Text Block]	ACQUISITIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans) In March 2016, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans purchased the Union Power Station, a 1,980 MW (summer rating) power generation facility located near El Dorado, Arkansas, from Union Power Partners, L.P. The Union Power Station consists of four natural gas-fired, combined-cycle gas turbine power blocks, each rated at 495 MW (summer rating). Entergy Louisiana purchased two of the power blocks and a 50% undivided ownership interest in certain assets related to the facility, and Entergy Arkansas and Entergy New Orleans each purchased one power block and a 25% undivided ownership interest in such related assets. The aggregate purchase price for the Union Power Station was approximately $949 million (approximately $237 million for each power block and associated assets).
Entergy Louisiana [Member]
Business Acquisition [Line Items]
Acquisitions [Text Block]	ACQUISITIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans) In March 2016, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans purchased the Union Power Station, a 1,980 MW (summer rating) power generation facility located near El Dorado, Arkansas, from Union Power Partners, L.P. The Union Power Station consists of four natural gas-fired, combined-cycle gas turbine power blocks, each rated at 495 MW (summer rating). Entergy Louisiana purchased two of the power blocks and a 50% undivided ownership interest in certain assets related to the facility, and Entergy Arkansas and Entergy New Orleans each purchased one power block and a 25% undivided ownership interest in such related assets. The aggregate purchase price for the Union Power Station was approximately $949 million (approximately $237 million for each power block and associated assets).
Entergy New Orleans [Member]
Business Acquisition [Line Items]
Acquisitions [Text Block]	ACQUISITIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans) In March 2016, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans purchased the Union Power Station, a 1,980 MW (summer rating) power generation facility located near El Dorado, Arkansas, from Union Power Partners, L.P. The Union Power Station consists of four natural gas-fired, combined-cycle gas turbine power blocks, each rated at 495 MW (summer rating). Entergy Louisiana purchased two of the power blocks and a 50% undivided ownership interest in certain assets related to the facility, and Entergy Arkansas and Entergy New Orleans each purchased one power block and a 25% undivided ownership interest in such related assets. The aggregate purchase price for the Union Power Station was approximately $949 million (approximately $237 million for each power block and associated assets).

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2016
Asset Retirement Obligation Disclosure [Text Block]	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. Following are updates to that discussion. Entergy expects that amounts available in Vermont Yankee’s decommissioning trust fund, including expected earnings, together with the credit facilities entered into in January 2015 that are expected to be repaid with recoveries from DOE litigation related to spent fuel storage, will be sufficient to cover Vermont Yankee’s expected costs of decommissioning, spent fuel management costs, and site restoration. In June 2015 the NRC staff issued an exemption from its regulations to allow Vermont Yankee to use its decommissioning trust fund to pay for approximately $225 million of estimated future spent fuel management costs that will not be paid for using funds from the credit facilities. In August 2015, Vermont and two Vermont utilities filed a petition in the U.S. Court of Appeals for the D.C. Circuit challenging the NRC’s issuance of that exemption. If that petition were to result in a final decision denying Vermont Yankee the exemption allowing the use of its decommissioning trust fund to pay for these spent fuel management costs, Vermont Yankee would have to satisfy the NRC that it had a plan to obtain additional funds to enable it to pay for these costs until the federal government takes possession of the fuel and removes it from the site. In February 2016 the court dismissed the petition as premature because Vermont and the utilities had requested the NRC to reconsider a number of issues related to Vermont Yankee's use of the decommissioning trust fund including use to pay for spent fuel management expenses pursuant to the exemption granted in June 2015. In October 2016 the NRC denied Vermont's and the utilities' request for a hearing and other relief but directed the NRC staff to conduct an assessment of any environmental impacts associated with the exemption. See Note 1 to the financial statements in the Form 10-K for further discussion regarding the Vermont Yankee plant. For the Indian Point 3 and FitzPatrick plants purchased in 2000 from NYPA, NYPA retained the decommissioning trusts and the decommissioning liabilities. NYPA and Entergy subsidiaries executed decommissioning agreements, which specified their decommissioning obligations. NYPA has the right to require the Entergy subsidiaries to assume each of the decommissioning liabilities provided that it assigns the corresponding decommissioning trust, up to a specified level, to the Entergy subsidiaries. Under the original agreements, if the decommissioning liabilities were retained by NYPA, the Entergy subsidiaries would perform the decommissioning of the plants at a price equal to the lesser of a pre-specified level or the amount in the decommissioning trusts. At the time of the acquisition of the plants Entergy recorded a contract asset that represented an estimate of the present value of the difference between the stipulated contract amount for decommissioning the plants less the decommissioning costs estimated in independent decommissioning cost studies. In August 2016, Entergy entered into a trust transfer agreement with NYPA to transfer the decommissioning trusts and decommissioning liabilities for the Indian Point 3 and FitzPatrick plants to Entergy. The transaction is contingent upon receiving approval from the NRC. As a result of the agreement with NYPA, in the third quarter 2016 Entergy removed the contract asset from its balance sheet, and recorded receivables for the beneficial interests in the decommissioning trust funds and asset retirement obligations for the decommissioning liabilities. The decommissioning and asset retirement cost liabilities on the consolidated balance sheet increased from $4,790 million at December 31, 2015 to $6,101 million at September 30, 2016 primarily due to recording the Indian Point 3 and FitzPatrick asset retirement obligations as a result of the agreement with NYPA.
Entergy Arkansas [Member]
Asset Retirement Obligation Disclosure [Text Block]	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. Following are updates to that discussion. Entergy expects that amounts available in Vermont Yankee’s decommissioning trust fund, including expected earnings, together with the credit facilities entered into in January 2015 that are expected to be repaid with recoveries from DOE litigation related to spent fuel storage, will be sufficient to cover Vermont Yankee’s expected costs of decommissioning, spent fuel management costs, and site restoration. In June 2015 the NRC staff issued an exemption from its regulations to allow Vermont Yankee to use its decommissioning trust fund to pay for approximately $225 million of estimated future spent fuel management costs that will not be paid for using funds from the credit facilities. In August 2015, Vermont and two Vermont utilities filed a petition in the U.S. Court of Appeals for the D.C. Circuit challenging the NRC’s issuance of that exemption. If that petition were to result in a final decision denying Vermont Yankee the exemption allowing the use of its decommissioning trust fund to pay for these spent fuel management costs, Vermont Yankee would have to satisfy the NRC that it had a plan to obtain additional funds to enable it to pay for these costs until the federal government takes possession of the fuel and removes it from the site. In February 2016 the court dismissed the petition as premature because Vermont and the utilities had requested the NRC to reconsider a number of issues related to Vermont Yankee's use of the decommissioning trust fund including use to pay for spent fuel management expenses pursuant to the exemption granted in June 2015. In October 2016 the NRC denied Vermont's and the utilities' request for a hearing and other relief but directed the NRC staff to conduct an assessment of any environmental impacts associated with the exemption. See Note 1 to the financial statements in the Form 10-K for further discussion regarding the Vermont Yankee plant. For the Indian Point 3 and FitzPatrick plants purchased in 2000 from NYPA, NYPA retained the decommissioning trusts and the decommissioning liabilities. NYPA and Entergy subsidiaries executed decommissioning agreements, which specified their decommissioning obligations. NYPA has the right to require the Entergy subsidiaries to assume each of the decommissioning liabilities provided that it assigns the corresponding decommissioning trust, up to a specified level, to the Entergy subsidiaries. Under the original agreements, if the decommissioning liabilities were retained by NYPA, the Entergy subsidiaries would perform the decommissioning of the plants at a price equal to the lesser of a pre-specified level or the amount in the decommissioning trusts. At the time of the acquisition of the plants Entergy recorded a contract asset that represented an estimate of the present value of the difference between the stipulated contract amount for decommissioning the plants less the decommissioning costs estimated in independent decommissioning cost studies. In August 2016, Entergy entered into a trust transfer agreement with NYPA to transfer the decommissioning trusts and decommissioning liabilities for the Indian Point 3 and FitzPatrick plants to Entergy. The transaction is contingent upon receiving approval from the NRC. As a result of the agreement with NYPA, in the third quarter 2016 Entergy removed the contract asset from its balance sheet, and recorded receivables for the beneficial interests in the decommissioning trust funds and asset retirement obligations for the decommissioning liabilities. The decommissioning and asset retirement cost liabilities on the consolidated balance sheet increased from $4,790 million at December 31, 2015 to $6,101 million at September 30, 2016 primarily due to recording the Indian Point 3 and FitzPatrick asset retirement obligations as a result of the agreement with NYPA.
Entergy Louisiana [Member]
Asset Retirement Obligation Disclosure [Text Block]	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. Following are updates to that discussion. Entergy expects that amounts available in Vermont Yankee’s decommissioning trust fund, including expected earnings, together with the credit facilities entered into in January 2015 that are expected to be repaid with recoveries from DOE litigation related to spent fuel storage, will be sufficient to cover Vermont Yankee’s expected costs of decommissioning, spent fuel management costs, and site restoration. In June 2015 the NRC staff issued an exemption from its regulations to allow Vermont Yankee to use its decommissioning trust fund to pay for approximately $225 million of estimated future spent fuel management costs that will not be paid for using funds from the credit facilities. In August 2015, Vermont and two Vermont utilities filed a petition in the U.S. Court of Appeals for the D.C. Circuit challenging the NRC’s issuance of that exemption. If that petition were to result in a final decision denying Vermont Yankee the exemption allowing the use of its decommissioning trust fund to pay for these spent fuel management costs, Vermont Yankee would have to satisfy the NRC that it had a plan to obtain additional funds to enable it to pay for these costs until the federal government takes possession of the fuel and removes it from the site. In February 2016 the court dismissed the petition as premature because Vermont and the utilities had requested the NRC to reconsider a number of issues related to Vermont Yankee's use of the decommissioning trust fund including use to pay for spent fuel management expenses pursuant to the exemption granted in June 2015. In October 2016 the NRC denied Vermont's and the utilities' request for a hearing and other relief but directed the NRC staff to conduct an assessment of any environmental impacts associated with the exemption. See Note 1 to the financial statements in the Form 10-K for further discussion regarding the Vermont Yankee plant. For the Indian Point 3 and FitzPatrick plants purchased in 2000 from NYPA, NYPA retained the decommissioning trusts and the decommissioning liabilities. NYPA and Entergy subsidiaries executed decommissioning agreements, which specified their decommissioning obligations. NYPA has the right to require the Entergy subsidiaries to assume each of the decommissioning liabilities provided that it assigns the corresponding decommissioning trust, up to a specified level, to the Entergy subsidiaries. Under the original agreements, if the decommissioning liabilities were retained by NYPA, the Entergy subsidiaries would perform the decommissioning of the plants at a price equal to the lesser of a pre-specified level or the amount in the decommissioning trusts. At the time of the acquisition of the plants Entergy recorded a contract asset that represented an estimate of the present value of the difference between the stipulated contract amount for decommissioning the plants less the decommissioning costs estimated in independent decommissioning cost studies. In August 2016, Entergy entered into a trust transfer agreement with NYPA to transfer the decommissioning trusts and decommissioning liabilities for the Indian Point 3 and FitzPatrick plants to Entergy. The transaction is contingent upon receiving approval from the NRC. As a result of the agreement with NYPA, in the third quarter 2016 Entergy removed the contract asset from its balance sheet, and recorded receivables for the beneficial interests in the decommissioning trust funds and asset retirement obligations for the decommissioning liabilities. The decommissioning and asset retirement cost liabilities on the consolidated balance sheet increased from $4,790 million at December 31, 2015 to $6,101 million at September 30, 2016 primarily due to recording the Indian Point 3 and FitzPatrick asset retirement obligations as a result of the agreement with NYPA.
Entergy Mississippi [Member]
Asset Retirement Obligation Disclosure [Text Block]	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. Following are updates to that discussion. Entergy expects that amounts available in Vermont Yankee’s decommissioning trust fund, including expected earnings, together with the credit facilities entered into in January 2015 that are expected to be repaid with recoveries from DOE litigation related to spent fuel storage, will be sufficient to cover Vermont Yankee’s expected costs of decommissioning, spent fuel management costs, and site restoration. In June 2015 the NRC staff issued an exemption from its regulations to allow Vermont Yankee to use its decommissioning trust fund to pay for approximately $225 million of estimated future spent fuel management costs that will not be paid for using funds from the credit facilities. In August 2015, Vermont and two Vermont utilities filed a petition in the U.S. Court of Appeals for the D.C. Circuit challenging the NRC’s issuance of that exemption. If that petition were to result in a final decision denying Vermont Yankee the exemption allowing the use of its decommissioning trust fund to pay for these spent fuel management costs, Vermont Yankee would have to satisfy the NRC that it had a plan to obtain additional funds to enable it to pay for these costs until the federal government takes possession of the fuel and removes it from the site. In February 2016 the court dismissed the petition as premature because Vermont and the utilities had requested the NRC to reconsider a number of issues related to Vermont Yankee's use of the decommissioning trust fund including use to pay for spent fuel management expenses pursuant to the exemption granted in June 2015. In October 2016 the NRC denied Vermont's and the utilities' request for a hearing and other relief but directed the NRC staff to conduct an assessment of any environmental impacts associated with the exemption. See Note 1 to the financial statements in the Form 10-K for further discussion regarding the Vermont Yankee plant. For the Indian Point 3 and FitzPatrick plants purchased in 2000 from NYPA, NYPA retained the decommissioning trusts and the decommissioning liabilities. NYPA and Entergy subsidiaries executed decommissioning agreements, which specified their decommissioning obligations. NYPA has the right to require the Entergy subsidiaries to assume each of the decommissioning liabilities provided that it assigns the corresponding decommissioning trust, up to a specified level, to the Entergy subsidiaries. Under the original agreements, if the decommissioning liabilities were retained by NYPA, the Entergy subsidiaries would perform the decommissioning of the plants at a price equal to the lesser of a pre-specified level or the amount in the decommissioning trusts. At the time of the acquisition of the plants Entergy recorded a contract asset that represented an estimate of the present value of the difference between the stipulated contract amount for decommissioning the plants less the decommissioning costs estimated in independent decommissioning cost studies. In August 2016, Entergy entered into a trust transfer agreement with NYPA to transfer the decommissioning trusts and decommissioning liabilities for the Indian Point 3 and FitzPatrick plants to Entergy. The transaction is contingent upon receiving approval from the NRC. As a result of the agreement with NYPA, in the third quarter 2016 Entergy removed the contract asset from its balance sheet, and recorded receivables for the beneficial interests in the decommissioning trust funds and asset retirement obligations for the decommissioning liabilities. The decommissioning and asset retirement cost liabilities on the consolidated balance sheet increased from $4,790 million at December 31, 2015 to $6,101 million at September 30, 2016 primarily due to recording the Indian Point 3 and FitzPatrick asset retirement obligations as a result of the agreement with NYPA.
Entergy New Orleans [Member]
Asset Retirement Obligation Disclosure [Text Block]	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. Following are updates to that discussion. Entergy expects that amounts available in Vermont Yankee’s decommissioning trust fund, including expected earnings, together with the credit facilities entered into in January 2015 that are expected to be repaid with recoveries from DOE litigation related to spent fuel storage, will be sufficient to cover Vermont Yankee’s expected costs of decommissioning, spent fuel management costs, and site restoration. In June 2015 the NRC staff issued an exemption from its regulations to allow Vermont Yankee to use its decommissioning trust fund to pay for approximately $225 million of estimated future spent fuel management costs that will not be paid for using funds from the credit facilities. In August 2015, Vermont and two Vermont utilities filed a petition in the U.S. Court of Appeals for the D.C. Circuit challenging the NRC’s issuance of that exemption. If that petition were to result in a final decision denying Vermont Yankee the exemption allowing the use of its decommissioning trust fund to pay for these spent fuel management costs, Vermont Yankee would have to satisfy the NRC that it had a plan to obtain additional funds to enable it to pay for these costs until the federal government takes possession of the fuel and removes it from the site. In February 2016 the court dismissed the petition as premature because Vermont and the utilities had requested the NRC to reconsider a number of issues related to Vermont Yankee's use of the decommissioning trust fund including use to pay for spent fuel management expenses pursuant to the exemption granted in June 2015. In October 2016 the NRC denied Vermont's and the utilities' request for a hearing and other relief but directed the NRC staff to conduct an assessment of any environmental impacts associated with the exemption. See Note 1 to the financial statements in the Form 10-K for further discussion regarding the Vermont Yankee plant. For the Indian Point 3 and FitzPatrick plants purchased in 2000 from NYPA, NYPA retained the decommissioning trusts and the decommissioning liabilities. NYPA and Entergy subsidiaries executed decommissioning agreements, which specified their decommissioning obligations. NYPA has the right to require the Entergy subsidiaries to assume each of the decommissioning liabilities provided that it assigns the corresponding decommissioning trust, up to a specified level, to the Entergy subsidiaries. Under the original agreements, if the decommissioning liabilities were retained by NYPA, the Entergy subsidiaries would perform the decommissioning of the plants at a price equal to the lesser of a pre-specified level or the amount in the decommissioning trusts. At the time of the acquisition of the plants Entergy recorded a contract asset that represented an estimate of the present value of the difference between the stipulated contract amount for decommissioning the plants less the decommissioning costs estimated in independent decommissioning cost studies. In August 2016, Entergy entered into a trust transfer agreement with NYPA to transfer the decommissioning trusts and decommissioning liabilities for the Indian Point 3 and FitzPatrick plants to Entergy. The transaction is contingent upon receiving approval from the NRC. As a result of the agreement with NYPA, in the third quarter 2016 Entergy removed the contract asset from its balance sheet, and recorded receivables for the beneficial interests in the decommissioning trust funds and asset retirement obligations for the decommissioning liabilities. The decommissioning and asset retirement cost liabilities on the consolidated balance sheet increased from $4,790 million at December 31, 2015 to $6,101 million at September 30, 2016 primarily due to recording the Indian Point 3 and FitzPatrick asset retirement obligations as a result of the agreement with NYPA.
Entergy Texas [Member]
Asset Retirement Obligation Disclosure [Text Block]	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. Following are updates to that discussion. Entergy expects that amounts available in Vermont Yankee’s decommissioning trust fund, including expected earnings, together with the credit facilities entered into in January 2015 that are expected to be repaid with recoveries from DOE litigation related to spent fuel storage, will be sufficient to cover Vermont Yankee’s expected costs of decommissioning, spent fuel management costs, and site restoration. In June 2015 the NRC staff issued an exemption from its regulations to allow Vermont Yankee to use its decommissioning trust fund to pay for approximately $225 million of estimated future spent fuel management costs that will not be paid for using funds from the credit facilities. In August 2015, Vermont and two Vermont utilities filed a petition in the U.S. Court of Appeals for the D.C. Circuit challenging the NRC’s issuance of that exemption. If that petition were to result in a final decision denying Vermont Yankee the exemption allowing the use of its decommissioning trust fund to pay for these spent fuel management costs, Vermont Yankee would have to satisfy the NRC that it had a plan to obtain additional funds to enable it to pay for these costs until the federal government takes possession of the fuel and removes it from the site. In February 2016 the court dismissed the petition as premature because Vermont and the utilities had requested the NRC to reconsider a number of issues related to Vermont Yankee's use of the decommissioning trust fund including use to pay for spent fuel management expenses pursuant to the exemption granted in June 2015. In October 2016 the NRC denied Vermont's and the utilities' request for a hearing and other relief but directed the NRC staff to conduct an assessment of any environmental impacts associated with the exemption. See Note 1 to the financial statements in the Form 10-K for further discussion regarding the Vermont Yankee plant. For the Indian Point 3 and FitzPatrick plants purchased in 2000 from NYPA, NYPA retained the decommissioning trusts and the decommissioning liabilities. NYPA and Entergy subsidiaries executed decommissioning agreements, which specified their decommissioning obligations. NYPA has the right to require the Entergy subsidiaries to assume each of the decommissioning liabilities provided that it assigns the corresponding decommissioning trust, up to a specified level, to the Entergy subsidiaries. Under the original agreements, if the decommissioning liabilities were retained by NYPA, the Entergy subsidiaries would perform the decommissioning of the plants at a price equal to the lesser of a pre-specified level or the amount in the decommissioning trusts. At the time of the acquisition of the plants Entergy recorded a contract asset that represented an estimate of the present value of the difference between the stipulated contract amount for decommissioning the plants less the decommissioning costs estimated in independent decommissioning cost studies. In August 2016, Entergy entered into a trust transfer agreement with NYPA to transfer the decommissioning trusts and decommissioning liabilities for the Indian Point 3 and FitzPatrick plants to Entergy. The transaction is contingent upon receiving approval from the NRC. As a result of the agreement with NYPA, in the third quarter 2016 Entergy removed the contract asset from its balance sheet, and recorded receivables for the beneficial interests in the decommissioning trust funds and asset retirement obligations for the decommissioning liabilities. The decommissioning and asset retirement cost liabilities on the consolidated balance sheet increased from $4,790 million at December 31, 2015 to $6,101 million at September 30, 2016 primarily due to recording the Indian Point 3 and FitzPatrick asset retirement obligations as a result of the agreement with NYPA.
System Energy [Member]
Asset Retirement Obligation Disclosure [Text Block]	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. Following are updates to that discussion. Entergy expects that amounts available in Vermont Yankee’s decommissioning trust fund, including expected earnings, together with the credit facilities entered into in January 2015 that are expected to be repaid with recoveries from DOE litigation related to spent fuel storage, will be sufficient to cover Vermont Yankee’s expected costs of decommissioning, spent fuel management costs, and site restoration. In June 2015 the NRC staff issued an exemption from its regulations to allow Vermont Yankee to use its decommissioning trust fund to pay for approximately $225 million of estimated future spent fuel management costs that will not be paid for using funds from the credit facilities. In August 2015, Vermont and two Vermont utilities filed a petition in the U.S. Court of Appeals for the D.C. Circuit challenging the NRC’s issuance of that exemption. If that petition were to result in a final decision denying Vermont Yankee the exemption allowing the use of its decommissioning trust fund to pay for these spent fuel management costs, Vermont Yankee would have to satisfy the NRC that it had a plan to obtain additional funds to enable it to pay for these costs until the federal government takes possession of the fuel and removes it from the site. In February 2016 the court dismissed the petition as premature because Vermont and the utilities had requested the NRC to reconsider a number of issues related to Vermont Yankee's use of the decommissioning trust fund including use to pay for spent fuel management expenses pursuant to the exemption granted in June 2015. In October 2016 the NRC denied Vermont's and the utilities' request for a hearing and other relief but directed the NRC staff to conduct an assessment of any environmental impacts associated with the exemption. See Note 1 to the financial statements in the Form 10-K for further discussion regarding the Vermont Yankee plant. For the Indian Point 3 and FitzPatrick plants purchased in 2000 from NYPA, NYPA retained the decommissioning trusts and the decommissioning liabilities. NYPA and Entergy subsidiaries executed decommissioning agreements, which specified their decommissioning obligations. NYPA has the right to require the Entergy subsidiaries to assume each of the decommissioning liabilities provided that it assigns the corresponding decommissioning trust, up to a specified level, to the Entergy subsidiaries. Under the original agreements, if the decommissioning liabilities were retained by NYPA, the Entergy subsidiaries would perform the decommissioning of the plants at a price equal to the lesser of a pre-specified level or the amount in the decommissioning trusts. At the time of the acquisition of the plants Entergy recorded a contract asset that represented an estimate of the present value of the difference between the stipulated contract amount for decommissioning the plants less the decommissioning costs estimated in independent decommissioning cost studies. In August 2016, Entergy entered into a trust transfer agreement with NYPA to transfer the decommissioning trusts and decommissioning liabilities for the Indian Point 3 and FitzPatrick plants to Entergy. The transaction is contingent upon receiving approval from the NRC. As a result of the agreement with NYPA, in the third quarter 2016 Entergy removed the contract asset from its balance sheet, and recorded receivables for the beneficial interests in the decommissioning trust funds and asset retirement obligations for the decommissioning liabilities. The decommissioning and asset retirement cost liabilities on the consolidated balance sheet increased from $4,790 million at December 31, 2015 to $6,101 million at September 30, 2016 primarily due to recording the Indian Point 3 and FitzPatrick asset retirement obligations as a result of the agreement with NYPA.

Equity (Tables)

Equity (Tables)	9 Months Ended
	Sep. 30, 2016
Schedule Of Earnings Per Share Basic And Diluted	The following table presents Entergy’s basic and diluted earnings (loss) per share calculations included on the consolidated statements of operations: For the Three Months Ended September 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings (loss) per share Income Shares $/share Loss Shares $/share Net income (loss) attributable to Entergy Corporation $388.2 179.0 $2.17 ($723.0 ) 179.2 ($4.04 ) Average dilutive effect of: Stock options 0.3 — — — Other equity plans 0.7 (0.01 ) — — Diluted earnings (loss) per share $388.2 180.0 $2.16 ($723.0 ) 179.2 ($4.04 ) The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 3.5 million for the three months ended September 30, 2016 and approximately 7.4 million for the three months ended September 30, 2015 . For the Nine Months Ended September 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings (loss) per share Income Shares $/share Loss Shares $/share Net income (loss) attributable to Entergy Corporation $1,185.4 178.8 $6.63 ($276.1 ) 179.4 ($1.54 ) Average dilutive effect of: Stock options 0.2 (0.01 ) — — Other equity plans 0.5 (0.02 ) — — Diluted earnings (loss) per share $1,185.4 179.5 $6.60 ($276.1 ) 179.4 ($1.54 )
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, 2016 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, July 1, 2016 $32,423 ($453,999 ) $411,581 $840 ($9,155 ) Other comprehensive income (loss) before reclassifications 45,162 — 23,039 (92 ) 68,109 Amounts reclassified from accumulated other comprehensive income (loss) (24,190 ) 5,044 (1,672 ) — (20,818 ) Net other comprehensive income (loss) for the period 20,972 5,044 21,367 (92 ) 47,291 Ending balance, September 30, 2016 $53,395 ($448,955 ) $432,948 $748 $38,136 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2015 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, July 1, 2015 $107,484 ($553,903 ) $396,818 $2,785 ($46,816 ) Other comprehensive income (loss) before reclassifications 31,620 — (50,760 ) (469 ) (19,609 ) Amounts reclassified from accumulated other comprehensive income (loss) (55,604 ) 7,437 (3,206 ) — (51,373 ) Net other comprehensive income (loss) for the period (23,984 ) 7,437 (53,966 ) (469 ) (70,982 ) Ending balance, September 30, 2015 $83,500 ($546,466 ) $342,852 $2,316 ($117,798 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2016 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, 2016 $105,970 ($466,604 ) $367,557 $2,028 $8,951 Other comprehensive income (loss) before reclassifications 101,071 — 72,087 (1,280 ) 171,878 Amounts reclassified from accumulated other comprehensive income (loss) (153,646 ) 17,649 (6,696 ) — (142,693 ) Net other comprehensive income (loss) for the period (52,575 ) 17,649 65,391 (1,280 ) 29,185 Ending balance, September 30, 2016 $53,395 ($448,955 ) $432,948 $748 $38,136 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2015 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, 2015 $98,118 ($569,789 ) $426,695 $2,669 ($42,307 ) Other comprehensive income (loss) before reclassifications 99,520 13 (63,210 ) (353 ) 35,970 Amounts reclassified from accumulated other comprehensive income (loss) (114,138 ) 23,310 (20,633 ) — (111,461 ) Net other comprehensive income (loss) for the period (14,618 ) 23,323 (83,843 ) (353 ) (75,491 ) Ending balance, September 30, 2015 $83,500 ($546,466 ) $342,852 $2,316 ($117,798 )
Reclassification out of Accumulated Other Comprehensive Income	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended September 30, 2016 are as follows: Amounts reclassified from AOCI Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $37,550 Competitive business operating revenues Interest rate swaps (334 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 37,216 (13,026 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $24,190 Pension and other postretirement liabilities Amortization of prior-service credit $7,354 (a) Amortization of loss (15,183 ) (a) Settlement loss (1,279 ) (a) Total amortization (9,108 ) 4,064 Income taxes Total amortization (net of tax) ($5,044 ) Net unrealized investment gain (loss) Realized gain (loss) $3,279 Interest and investment income (1,607 ) Income taxes Total realized investment gain (loss) (net of tax) $1,672 Total reclassifications for the period (net of tax) $20,818 (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) for Entergy for the three months ended September 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $86,020 Competitive business operating revenues Interest rate swaps (477 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 85,543 (29,939 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $55,604 Pension and other postretirement liabilities Amortization of prior-service credit $5,985 (a) Amortization of loss (17,588 ) (a) Total amortization (11,603 ) 4,166 Income taxes Total amortization (net of tax) ($7,437 ) Net unrealized investment gain (loss) Realized gain (loss) $6,286 Interest and investment income (3,080 ) Income taxes Total realized investment gain (loss) (net of tax) $3,206 Total reclassifications for the period (net of tax) $51,373 (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) for Entergy for the nine months ended September 30, 2016 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $237,483 Competitive business operating revenues Interest rate swaps (1,104 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 236,379 (82,733 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $153,646 Pension and other postretirement liabilities Amortization of prior-service credit $22,064 (a) Amortization of loss (45,535 ) (a) Settlement loss (1,279 ) (a) Total amortization (24,750 ) 7,101 Income taxes Total amortization (net of tax) ($17,649 ) Net unrealized investment gain (loss) Realized gain (loss) $13,129 Interest and investment income (6,433 ) Income taxes Total realized investment gain (loss) (net of tax) $6,696 Total reclassifications for the period (net of tax) $142,693 (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) for Entergy for the nine months ended September 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $177,129 Competitive business operating revenues Interest rate swaps (1,533 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 175,596 (61,458 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $114,138 Pension and other postretirement liabilities Amortization of prior-service credit $17,956 (a) Amortization of loss (52,764 ) (a) Total amortization (34,808 ) 11,498 Income taxes Total amortization (net of tax) ($23,310 ) Net unrealized investment gain (loss) Realized gain (loss) $40,457 Interest and investment income (19,824 ) Income taxes Total realized investment gain (loss) (net of tax) $20,633 Total reclassifications for the period (net of tax) $111,461 (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, 2016 : Pension and Other (In Thousands) Beginning balance July 1, 2016 ($56,905 ) Amounts reclassified from accumulated other (232 ) Net other comprehensive income (loss) for the period (232 ) Ending balance, September 30, 2016 ($57,137 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2015 : Pension and Other (In Thousands) Beginning balance July 1, 2015 ($78,431 ) Amounts reclassified from accumulated other 412 Net other comprehensive income (loss) for the period 412 Ending balance, September 30, 2015 ($78,019 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2016 : Pension and Other (In Thousands) Beginning balance, January 1, 2016 ($56,412 ) Amounts reclassified from accumulated other (725 ) Net other comprehensive income (loss) for the period (725 ) Ending balance, September 30, 2016 ($57,137 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2015 : Pension and Other (In Thousands) Beginning balance, January 1, 2015 ($79,223 ) Amounts reclassified from accumulated other 1,204 Net other comprehensive income (loss) for the period 1,204 Ending balance, September 30, 2015 ($78,019 )
Reclassification out of Accumulated Other Comprehensive Income	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the three months ended September 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,947 (a) Amortization of loss (1,570 ) (a) Total amortization 377 (145 ) Income taxes Total amortization (net of tax) 232 Total reclassifications for the period (net of tax) $232 (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) for Entergy Louisiana for the three months ended September 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,866 (a) Amortization of loss (2,536 ) (a) Total amortization (670 ) 258 Income taxes Total amortization (net of tax) (412 ) Total reclassifications for the period (net of tax) ($412 ) (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) for Entergy Louisiana for the nine months ended September 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,841 (a) Amortization of loss (4,712 ) (a) Total amortization 1,129 (404 ) Income taxes Total amortization (net of tax) 725 Total reclassifications for the period (net of tax) $725 (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) for Entergy Louisiana for the nine months ended September 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $5,599 (a) Amortization of loss (7,606 ) (a) Total amortization (2,007 ) 803 Income taxes Total amortization (net of tax) (1,204 ) Total reclassifications for the period (net of tax) ($1,204 ) (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, 25

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2016
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, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $180 $6 $3,314
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2016 Letters of Credit Outstanding as of September 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.77% $— $— Entergy Arkansas August 2021 $150 million (c) 1.77% $— $— Entergy Louisiana August 2021 $350 million (d) 1.77% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 2.02% $— $— Entergy Mississippi May 2017 $35 million (e) 2.02% $— $— Entergy Mississippi May 2017 $20 million (e) 2.02% $— $— Entergy Mississippi May 2017 $10 million (e) 2.02% $— $— Entergy New Orleans November 2018 $25 million (f) 2.27% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.02% $— $4.7 million (a) The interest rate is the rate as of September 30, 2016 that would most likely apply 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 allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.
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, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2016 Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $16.4 million Entergy Mississippi $40 million 0.70% $10.2 million Entergy New Orleans $15 million 0.75% $12.9 million Entergy Texas $50 million 0.70% $16.0 million
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, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $49 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $12 System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of September 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.15% $47.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 2.14% $42.0 (b) System Energy VIE May 2019 $120 2.13% $80.0 (b) (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. (b) Commercial paper, classified as a current liability.
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, 2016 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Louisiana River Bend VIE 3.25% Series Q due July 2017 $75 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.25% Series G due July 2017 $25 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million System Energy VIE 4.02% Series H due February 2017 $50 million System Energy VIE 3.78% Series I due October 2018 $85 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, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,611,903 $15,424,412 Entergy Arkansas $2,796,059 $2,791,291 Entergy Louisiana $5,407,897 $5,848,345 Entergy Mississippi $1,344,305 $1,409,719 Entergy New Orleans $459,295 $502,194 Entergy Texas $1,521,270 $1,683,655 System Energy $551,023 $543,933 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 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 and are based on prices derived from inputs such as benchmark yields and reported trades. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2015 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,325,930 $13,578,511 Entergy Arkansas $2,629,839 $2,498,108 Entergy Louisiana $4,836,162 $5,018,786 Entergy Mississippi $1,045,085 $1,087,326 Entergy New Orleans $342,880 $351,040 Entergy Texas $1,451,967 $1,590,616 System Energy $572,667 $552,762 (a) The values exclude lease obligations of $109 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $35 million at Entergy, 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 and are based on prices derived from inputs such as benchmark yields and reported trades.
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, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2016 Letters of Credit Outstanding as of September 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.77% $— $— Entergy Arkansas August 2021 $150 million (c) 1.77% $— $— Entergy Louisiana August 2021 $350 million (d) 1.77% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 2.02% $— $— Entergy Mississippi May 2017 $35 million (e) 2.02% $— $— Entergy Mississippi May 2017 $20 million (e) 2.02% $— $— Entergy Mississippi May 2017 $10 million (e) 2.02% $— $— Entergy New Orleans November 2018 $25 million (f) 2.27% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.02% $— $4.7 million (a) The interest rate is the rate as of September 30, 2016 that would most likely apply 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 allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.
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, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2016 Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $16.4 million Entergy Mississippi $40 million 0.70% $10.2 million Entergy New Orleans $15 million 0.75% $12.9 million Entergy Texas $50 million 0.70% $16.0 million
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, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $49 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $12 System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of September 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.15% $47.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 2.14% $42.0 (b) System Energy VIE May 2019 $120 2.13% $80.0 (b) (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. (b) Commercial paper, classified as a current liability.
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, 2016 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Louisiana River Bend VIE 3.25% Series Q due July 2017 $75 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.25% Series G due July 2017 $25 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million System Energy VIE 4.02% Series H due February 2017 $50 million System Energy VIE 3.78% Series I due October 2018 $85 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, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,611,903 $15,424,412 Entergy Arkansas $2,796,059 $2,791,291 Entergy Louisiana $5,407,897 $5,848,345 Entergy Mississippi $1,344,305 $1,409,719 Entergy New Orleans $459,295 $502,194 Entergy Texas $1,521,270 $1,683,655 System Energy $551,023 $543,933 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 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 and are based on prices derived from inputs such as benchmark yields and reported trades. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2015 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,325,930 $13,578,511 Entergy Arkansas $2,629,839 $2,498,108 Entergy Louisiana $4,836,162 $5,018,786 Entergy Mississippi $1,045,085 $1,087,326 Entergy New Orleans $342,880 $351,040 Entergy Texas $1,451,967 $1,590,616 System Energy $572,667 $552,762 (a) The values exclude lease obligations of $109 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $35 million at Entergy, 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 and are based on prices derived from inputs such as benchmark yields and reported trades.
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, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2016 Letters of Credit Outstanding as of September 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.77% $— $— Entergy Arkansas August 2021 $150 million (c) 1.77% $— $— Entergy Louisiana August 2021 $350 million (d) 1.77% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 2.02% $— $— Entergy Mississippi May 2017 $35 million (e) 2.02% $— $— Entergy Mississippi May 2017 $20 million (e) 2.02% $— $— Entergy Mississippi May 2017 $10 million (e) 2.02% $— $— Entergy New Orleans November 2018 $25 million (f) 2.27% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.02% $— $4.7 million (a) The interest rate is the rate as of September 30, 2016 that would most likely apply 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 allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.
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, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2016 Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $16.4 million Entergy Mississippi $40 million 0.70% $10.2 million Entergy New Orleans $15 million 0.75% $12.9 million Entergy Texas $50 million 0.70% $16.0 million
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, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $49 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $12 System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of September 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.15% $47.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 2.14% $42.0 (b) System Energy VIE May 2019 $120 2.13% $80.0 (b) (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. (b) Commercial paper, classified as a current liability.
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, 2016 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Louisiana River Bend VIE 3.25% Series Q due July 2017 $75 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.25% Series G due July 2017 $25 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million System Energy VIE 4.02% Series H due February 2017 $50 million System Energy VIE 3.78% Series I due October 2018 $85 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, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,611,903 $15,424,412 Entergy Arkansas $2,796,059 $2,791,291 Entergy Louisiana $5,407,897 $5,848,345 Entergy Mississippi $1,344,305 $1,409,719 Entergy New Orleans $459,295 $502,194 Entergy Texas $1,521,270 $1,683,655 System Energy $551,023 $543,933 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 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 and are based on prices derived from inputs such as benchmark yields and reported trades. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2015 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,325,930 $13,578,511 Entergy Arkansas $2,629,839 $2,498,108 Entergy Louisiana $4,836,162 $5,018,786 Entergy Mississippi $1,045,085 $1,087,326 Entergy New Orleans $342,880 $351,040 Entergy Texas $1,451,967 $1,590,616 System Energy $572,667 $552,762 (a) The values exclude lease obligations of $109 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $35 million at Entergy, 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 and are based on prices derived from inputs such as benchmark yields and reported trades.
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, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2016 Letters of Credit Outstanding as of September 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.77% $— $— Entergy Arkansas August 2021 $150 million (c) 1.77% $— $— Entergy Louisiana August 2021 $350 million (d) 1.77% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 2.02% $— $— Entergy Mississippi May 2017 $35 million (e) 2.02% $— $— Entergy Mississippi May 2017 $20 million (e) 2.02% $— $— Entergy Mississippi May 2017 $10 million (e) 2.02% $— $— Entergy New Orleans November 2018 $25 million (f) 2.27% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.02% $— $4.7 million (a) The interest rate is the rate as of September 30, 2016 that would most likely apply 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 allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.
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, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2016 Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $16.4 million Entergy Mississippi $40 million 0.70% $10.2 million Entergy New Orleans $15 million 0.75% $12.9 million Entergy Texas $50 million 0.70% $16.0 million
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, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $49 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $12 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, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,611,903 $15,424,412 Entergy Arkansas $2,796,059 $2,791,291 Entergy Louisiana $5,407,897 $5,848,345 Entergy Mississippi $1,344,305 $1,409,719 Entergy New Orleans $459,295 $502,194 Entergy Texas $1,521,270 $1,683,655 System Energy $551,023 $543,933 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 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 and are based on prices derived from inputs such as benchmark yields and reported trades. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2015 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,325,930 $13,578,511 Entergy Arkansas $2,629,839 $2,498,108 Entergy Louisiana $4,836,162 $5,018,786 Entergy Mississippi $1,045,085 $1,087,326 Entergy New Orleans $342,880 $351,040 Entergy Texas $1,451,967 $1,590,616 System Energy $572,667 $552,762 (a) The values exclude lease obligations of $109 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $35 million at Entergy, 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 and are based on prices derived from inputs such as benchmark yields and reported trades.
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, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2016 Letters of Credit Outstanding as of September 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.77% $— $— Entergy Arkansas August 2021 $150 million (c) 1.77% $— $— Entergy Louisiana August 2021 $350 million (d) 1.77% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 2.02% $— $— Entergy Mississippi May 2017 $35 million (e) 2.02% $— $— Entergy Mississippi May 2017 $20 million (e) 2.02% $— $— Entergy Mississippi May 2017 $10 million (e) 2.02% $— $— Entergy New Orleans November 2018 $25 million (f) 2.27% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.02% $— $4.7 million (a) The interest rate is the rate as of September 30, 2016 that would most likely apply 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 allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.
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, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2016 Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $16.4 million Entergy Mississippi $40 million 0.70% $10.2 million Entergy New Orleans $15 million 0.75% $12.9 million Entergy Texas $50 million 0.70% $16.0 million
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, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $49 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $12 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, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,611,903 $15,424,412 Entergy Arkansas $2,796,059 $2,791,291 Entergy Louisiana $5,407,897 $5,848,345 Entergy Mississippi $1,344,305 $1,409,719 Entergy New Orleans $459,295 $502,194 Entergy Texas $1,521,270 $1,683,655 System Energy $551,023 $543,933 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 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 and are based on prices derived from inputs such as benchmark yields and reported trades. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2015 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,325,930 $13,578,511 Entergy Arkansas $2,629,839 $2,498,108 Entergy Louisiana $4,836,162 $5,018,786 Entergy Mississippi $1,045,085 $1,087,326 Entergy New Orleans $342,880 $351,040 Entergy Texas $1,451,967 $1,590,616 System Energy $572,667 $552,762 (a) The values exclude lease obligations of $109 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $35 million at Entergy, 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 and are based on prices derived from inputs such as benchmark yields and reported trades.
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, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of September 30, 2016 Letters of Credit Outstanding as of September 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.77% $— $— Entergy Arkansas August 2021 $150 million (c) 1.77% $— $— Entergy Louisiana August 2021 $350 million (d) 1.77% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 2.02% $— $— Entergy Mississippi May 2017 $35 million (e) 2.02% $— $— Entergy Mississippi May 2017 $20 million (e) 2.02% $— $— Entergy Mississippi May 2017 $10 million (e) 2.02% $— $— Entergy New Orleans November 2018 $25 million (f) 2.27% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.02% $— $4.7 million (a) The interest rate is the rate as of September 30, 2016 that would most likely apply 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 allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.
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, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of September 30, 2016 Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $16.4 million Entergy Mississippi $40 million 0.70% $10.2 million Entergy New Orleans $15 million 0.75% $12.9 million Entergy Texas $50 million 0.70% $16.0 million
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, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $49 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $12 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, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,611,903 $15,424,412 Entergy Arkansas $2,796,059 $2,791,291 Entergy Louisiana $5,407,897 $5,848,345 Entergy Mississippi $1,344,305 $1,409,719 Entergy New Orleans $459,295 $502,194 Entergy Texas $1,521,270 $1,683,655 System Energy $551,023 $543,933 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 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 and are based on prices derived from inputs such as benchmark yields and reported trades. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2015 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,325,930 $13,578,511 Entergy Arkansas $2,629,839 $2,498,108 Entergy Louisiana $4,836,162 $5,018,786 Entergy Mississippi $1,045,085 $1,087,326 Entergy New Orleans $342,880 $351,040 Entergy Texas $1,451,967 $1,590,616 System Energy $572,667 $552,762 (a) The values exclude lease obligations of $109 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $35 million at Entergy, 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 and are based on prices derived from inputs such as benchmark yields and reported trades.
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, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $49 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $12 System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of September 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of September 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.15% $47.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 2.14% $42.0 (b) System Energy VIE May 2019 $120 2.13% $80.0 (b) (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. (b) Commercial paper, classified as a current liability.
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, 2016 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Louisiana River Bend VIE 3.25% Series Q due July 2017 $75 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.25% Series G due July 2017 $25 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million System Energy VIE 4.02% Series H due February 2017 $50 million System Energy VIE 3.78% Series I due October 2018 $85 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, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,611,903 $15,424,412 Entergy Arkansas $2,796,059 $2,791,291 Entergy Louisiana $5,407,897 $5,848,345 Entergy Mississippi $1,344,305 $1,409,719 Entergy New Orleans $459,295 $502,194 Entergy Texas $1,521,270 $1,683,655 System Energy $551,023 $543,933 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 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 and are based on prices derived from inputs such as benchmark yields and reported trades. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2015 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,325,930 $13,578,511 Entergy Arkansas $2,629,839 $2,498,108 Entergy Louisiana $4,836,162 $5,018,786 Entergy Mississippi $1,045,085 $1,087,326 Entergy New Orleans $342,880 $351,040 Entergy Texas $1,451,967 $1,590,616 System Energy $572,667 $552,762 (a) The values exclude lease obligations of $109 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $35 million at Entergy, 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 and are based on prices derived from inputs such as benchmark yields and reported trades.

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2016
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, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $1.1 $1.1 Tax benefit recognized in Entergy’s net income $0.5 $0.4 Compensation cost capitalized as part of fixed assets and inventory $0.2 $0.1 The following table includes financial information for outstanding stock options for the nine months ended September 30, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $3.3 $3.2 Tax benefit recognized in Entergy’s net income $1.3 $1.2 Compensation cost capitalized as part of fixed assets and inventory $0.6 $0.5
Financial Information For Restricted Stock	The following table includes financial information for other outstanding equity awards for the three months ended September 30, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $8.5 $8.6 Tax benefit recognized in Entergy’s net income $3.3 $3.3 Compensation cost capitalized as part of fixed assets and inventory $2.0 $1.8 The following table includes financial information for other outstanding equity awards for the nine months ended September 30, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $25.4 $24.7 Tax benefit recognized in Entergy’s net income $9.8 $9.5 Compensation cost capitalized as part of fixed assets and inventory $5.7 $4.9

Retirement And Other Postreti27

Retirement And Other Postretirement Benefits (Tables)	9 Months Ended
	Sep. 30, 2016
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 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($114 ) $7,354 Amortization of loss (12,482 ) (2,063 ) (638 ) (15,183 ) Settlement loss — — (1,279 ) (1,279 ) ($12,752 ) $5,675 ($2,031 ) ($9,108 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (2 ) (1,570 ) ($836 ) $1,215 ($2 ) $377 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,780 ) (5 ) (2,536 ) ($751 ) $87 ($6 ) ($670 ) 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, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($810 ) $23,214 ($340 ) $22,064 Amortization of loss (37,446 ) (6,189 ) (1,900 ) (45,535 ) Settlement loss — — (1,279 ) (1,279 ) ($38,256 ) $17,025 ($3,519 ) ($24,750 ) Entergy Louisiana Amortization of prior service credit $— $5,841 $— $5,841 Amortization of loss (2,508 ) (2,196 ) (8 ) (4,712 ) ($2,508 ) $3,645 ($8 ) $1,129 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($1,167 ) $19,446 ($323 ) $17,956 Amortization of loss (37,881 ) (13,227 ) (1,656 ) (52,764 ) ($39,048 ) $6,219 ($1,979 ) ($34,808 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $5,601 ($2 ) $5,599 Amortization of loss (2,253 ) (5,338 ) (15 ) (7,606 ) ($2,253 ) $263 ($17 ) ($2,007 )
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 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $107,433 $131,286 Interest cost on projected benefit obligation 196,209 227,082 Expected return on assets (292,098 ) (295,965 ) Amortization of prior service cost 810 1,170 Amortization of loss 146,472 176,943 Special termination benefit — 76 Net pension costs $158,826 $240,592
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 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $24,219 $33,978 Interest cost on accumulated postretirement benefit obligation (APBO) 42,249 53,952 Expected return on assets (31,365 ) (34,032 ) Amortization of prior service credit (34,119 ) (27,960 ) Amortization of loss 13,662 23,679 Net other postretirement benefit cost $14,646 $49,617
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 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,543 $21,147 $4,686 $1,968 $4,248 $4,698 Interest cost on projected benefit obligation 39,165 44,610 11,433 5,442 10,671 8,976 Expected return on assets (59,316 ) (66,288 ) (17,943 ) (8,061 ) (18,186 ) (13,377 ) Amortization of loss 32,808 35,838 8,955 4,845 7,020 7,812 Net pension cost $28,200 $35,307 $7,131 $4,194 $3,753 $8,109 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $19,983 $25,797 $5,946 $2,547 $4,935 $5,871 Interest cost on projected benefit obligation 46,413 52,101 13,506 6,324 13,062 10,479 Expected return on assets (60,078 ) (68,103 ) (18,315 ) (8,175 ) (18,666 ) (13,704 ) Amortization of loss 40,692 44,853 11,172 6,039 9,714 9,792 Net pension cost $47,010 $54,648 $12,309 $6,735 $9,045 $12,438
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $390.1 million to its qualified pension plans in 2016. As of September 30, 2016 , Entergy had contributed $307.6 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 2016 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2016 pension contributions $83,001 $84,422 $19,968 $10,709 $15,920 $20,498 Pension contributions made through September 2016 $65,882 $67,116 $15,981 $8,456 $12,649 $16,120 Remaining estimated pension contributions to be made in 2016 $17,119 $17,306 $3,987 $2,253 $3,271 $4,378
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 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,934 $5,607 $1,158 $468 $1,194 $1,002 Interest cost on APBO 6,972 9,780 2,127 1,344 3,117 1,587 Expected return on assets (13,392 ) — (4,137 ) (3,462 ) (7,182 ) (2,442 ) Amortization of prior service credit (4,104 ) (5,841 ) (702 ) (558 ) (2,043 ) (1,179 ) Amortization of loss 3,192 2,196 669 111 1,611 861 Net other postretirement benefit cost ($4,398 ) $11,742 ($885 ) ($2,097 ) ($3,303 ) ($171 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,217 $7,422 $1,521 $615 $1,500 $1,410 Interest cost on APBO 9,390 12,234 2,577 1,956 4,026 1,884 Expected return on assets (14,394 ) — (4,626 ) (3,603 ) (7,764 ) (2,733 ) Amortization of prior service credit (1,830 ) (5,601 ) (687 ) (531 ) (2,043 ) (1,098 ) Amortization of loss 4,017 5,340 645 354 2,055 900 Net other postretirement benefit cost $2,400 $19,395 ($570 ) ($1,209 ) ($2,226 ) $363
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 in the third quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Third quarter 2016 $105 $58 $60 $16 $126 Third quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Nine months ended September 30, 2016 $317 $176 $179 $48 $380 Nine months ended September 30, 2015 $339 $204 $177 $48 $447
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 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($114 ) $7,354 Amortization of loss (12,482 ) (2,063 ) (638 ) (15,183 ) Settlement loss — — (1,279 ) (1,279 ) ($12,752 ) $5,675 ($2,031 ) ($9,108 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (2 ) (1,570 ) ($836 ) $1,215 ($2 ) $377 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,780 ) (5 ) (2,536 ) ($751 ) $87 ($6 ) ($670 ) 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, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($810 ) $23,214 ($340 ) $22,064 Amortization of loss (37,446 ) (6,189 ) (1,900 ) (45,535 ) Settlement loss — — (1,279 ) (1,279 ) ($38,256 ) $17,025 ($3,519 ) ($24,750 ) Entergy Louisiana Amortization of prior service credit $— $5,841 $— $5,841 Amortization of loss (2,508 ) (2,196 ) (8 ) (4,712 ) ($2,508 ) $3,645 ($8 ) $1,129 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($1,167 ) $19,446 ($323 ) $17,956 Amortization of loss (37,881 ) (13,227 ) (1,656 ) (52,764 ) ($39,048 ) $6,219 ($1,979 ) ($34,808 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $5,601 ($2 ) $5,599 Amortization of loss (2,253 ) (5,338 ) (15 ) (7,606 ) ($2,253 ) $263 ($17 ) ($2,007 )
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 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,543 $21,147 $4,686 $1,968 $4,248 $4,698 Interest cost on projected benefit obligation 39,165 44,610 11,433 5,442 10,671 8,976 Expected return on assets (59,316 ) (66,288 ) (17,943 ) (8,061 ) (18,186 ) (13,377 ) Amortization of loss 32,808 35,838 8,955 4,845 7,020 7,812 Net pension cost $28,200 $35,307 $7,131 $4,194 $3,753 $8,109 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $19,983 $25,797 $5,946 $2,547 $4,935 $5,871 Interest cost on projected benefit obligation 46,413 52,101 13,506 6,324 13,062 10,479 Expected return on assets (60,078 ) (68,103 ) (18,315 ) (8,175 ) (18,666 ) (13,704 ) Amortization of loss 40,692 44,853 11,172 6,039 9,714 9,792 Net pension cost $47,010 $54,648 $12,309 $6,735 $9,045 $12,438
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $390.1 million to its qualified pension plans in 2016. As of September 30, 2016 , Entergy had contributed $307.6 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 2016 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2016 pension contributions $83,001 $84,422 $19,968 $10,709 $15,920 $20,498 Pension contributions made through September 2016 $65,882 $67,116 $15,981 $8,456 $12,649 $16,120 Remaining estimated pension contributions to be made in 2016 $17,119 $17,306 $3,987 $2,253 $3,271 $4,378
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 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,934 $5,607 $1,158 $468 $1,194 $1,002 Interest cost on APBO 6,972 9,780 2,127 1,344 3,117 1,587 Expected return on assets (13,392 ) — (4,137 ) (3,462 ) (7,182 ) (2,442 ) Amortization of prior service credit (4,104 ) (5,841 ) (702 ) (558 ) (2,043 ) (1,179 ) Amortization of loss 3,192 2,196 669 111 1,611 861 Net other postretirement benefit cost ($4,398 ) $11,742 ($885 ) ($2,097 ) ($3,303 ) ($171 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,217 $7,422 $1,521 $615 $1,500 $1,410 Interest cost on APBO 9,390 12,234 2,577 1,956 4,026 1,884 Expected return on assets (14,394 ) — (4,626 ) (3,603 ) (7,764 ) (2,733 ) Amortization of prior service credit (1,830 ) (5,601 ) (687 ) (531 ) (2,043 ) (1,098 ) Amortization of loss 4,017 5,340 645 354 2,055 900 Net other postretirement benefit cost $2,400 $19,395 ($570 ) ($1,209 ) ($2,226 ) $363
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 in the third quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Third quarter 2016 $105 $58 $60 $16 $126 Third quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Nine months ended September 30, 2016 $317 $176 $179 $48 $380 Nine months ended September 30, 2015 $339 $204 $177 $48 $447
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 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,543 $21,147 $4,686 $1,968 $4,248 $4,698 Interest cost on projected benefit obligation 39,165 44,610 11,433 5,442 10,671 8,976 Expected return on assets (59,316 ) (66,288 ) (17,943 ) (8,061 ) (18,186 ) (13,377 ) Amortization of loss 32,808 35,838 8,955 4,845 7,020 7,812 Net pension cost $28,200 $35,307 $7,131 $4,194 $3,753 $8,109 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $19,983 $25,797 $5,946 $2,547 $4,935 $5,871 Interest cost on projected benefit obligation 46,413 52,101 13,506 6,324 13,062 10,479 Expected return on assets (60,078 ) (68,103 ) (18,315 ) (8,175 ) (18,666 ) (13,704 ) Amortization of loss 40,692 44,853 11,172 6,039 9,714 9,792 Net pension cost $47,010 $54,648 $12,309 $6,735 $9,045 $12,438
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $390.1 million to its qualified pension plans in 2016. As of September 30, 2016 , Entergy had contributed $307.6 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 2016 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2016 pension contributions $83,001 $84,422 $19,968 $10,709 $15,920 $20,498 Pension contributions made through September 2016 $65,882 $67,116 $15,981 $8,456 $12,649 $16,120 Remaining estimated pension contributions to be made in 2016 $17,119 $17,306 $3,987 $2,253 $3,271 $4,378
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 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,934 $5,607 $1,158 $468 $1,194 $1,002 Interest cost on APBO 6,972 9,780 2,127 1,344 3,117 1,587 Expected return on assets (13,392 ) — (4,137 ) (3,462 ) (7,182 ) (2,442 ) Amortization of prior service credit (4,104 ) (5,841 ) (702 ) (558 ) (2,043 ) (1,179 ) Amortization of loss 3,192 2,196 669 111 1,611 861 Net other postretirement benefit cost ($4,398 ) $11,742 ($885 ) ($2,097 ) ($3,303 ) ($171 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,217 $7,422 $1,521 $615 $1,500 $1,410 Interest cost on APBO 9,390 12,234 2,577 1,956 4,026 1,884 Expected return on assets (14,394 ) — (4,626 ) (3,603 ) (7,764 ) (2,733 ) Amortization of prior service credit (1,830 ) (5,601 ) (687 ) (531 ) (2,043 ) (1,098 ) Amortization of loss 4,017 5,340 645 354 2,055 900 Net other postretirement benefit cost $2,400 $19,395 ($570 ) ($1,209 ) ($2,226 ) $363
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 in the third quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Third quarter 2016 $105 $58 $60 $16 $126 Third quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Nine months ended September 30, 2016 $317 $176 $179 $48 $380 Nine months ended September 30, 2015 $339 $204 $177 $48 $447
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 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,543 $21,147 $4,686 $1,968 $4,248 $4,698 Interest cost on projected benefit obligation 39,165 44,610 11,433 5,442 10,671 8,976 Expected return on assets (59,316 ) (66,288 ) (17,943 ) (8,061 ) (18,186 ) (13,377 ) Amortization of loss 32,808 35,838 8,955 4,845 7,020 7,812 Net pension cost $28,200 $35,307 $7,131 $4,194 $3,753 $8,109 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $19,983 $25,797 $5,946 $2,547 $4,935 $5,871 Interest cost on projected benefit obligation 46,413 52,101 13,506 6,324 13,062 10,479 Expected return on assets (60,078 ) (68,103 ) (18,315 ) (8,175 ) (18,666 ) (13,704 ) Amortization of loss 40,692 44,853 11,172 6,039 9,714 9,792 Net pension cost $47,010 $54,648 $12,309 $6,735 $9,045 $12,438
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $390.1 million to its qualified pension plans in 2016. As of September 30, 2016 , Entergy had contributed $307.6 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 2016 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2016 pension contributions $83,001 $84,422 $19,968 $10,709 $15,920 $20,498 Pension contributions made through September 2016 $65,882 $67,116 $15,981 $8,456 $12,649 $16,120 Remaining estimated pension contributions to be made in 2016 $17,119 $17,306 $3,987 $2,253 $3,271 $4,378
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 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,934 $5,607 $1,158 $468 $1,194 $1,002 Interest cost on APBO 6,972 9,780 2,127 1,344 3,117 1,587 Expected return on assets (13,392 ) — (4,137 ) (3,462 ) (7,182 ) (2,442 ) Amortization of prior service credit (4,104 ) (5,841 ) (702 ) (558 ) (2,043 ) (1,179 ) Amortization of loss 3,192 2,196 669 111 1,611 861 Net other postretirement benefit cost ($4,398 ) $11,742 ($885 ) ($2,097 ) ($3,303 ) ($171 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,217 $7,422 $1,521 $615 $1,500 $1,410 Interest cost on APBO 9,390 12,234 2,577 1,956 4,026 1,884 Expected return on assets (14,394 ) — (4,626 ) (3,603 ) (7,764 ) (2,733 ) Amortization of prior service credit (1,830 ) (5,601 ) (687 ) (531 ) (2,043 ) (1,098 ) Amortization of loss 4,017 5,340 645 354 2,055 900 Net other postretirement benefit cost $2,400 $19,395 ($570 ) ($1,209 ) ($2,226 ) $363
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 in the third quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Third quarter 2016 $105 $58 $60 $16 $126 Third quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Nine months ended September 30, 2016 $317 $176 $179 $48 $380 Nine months ended September 30, 2015 $339 $204 $177 $48 $447
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 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,543 $21,147 $4,686 $1,968 $4,248 $4,698 Interest cost on projected benefit obligation 39,165 44,610 11,433 5,442 10,671 8,976 Expected return on assets (59,316 ) (66,288 ) (17,943 ) (8,061 ) (18,186 ) (13,377 ) Amortization of loss 32,808 35,838 8,955 4,845 7,020 7,812 Net pension cost $28,200 $35,307 $7,131 $4,194 $3,753 $8,109 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $19,983 $25,797 $5,946 $2,547 $4,935 $5,871 Interest cost on projected benefit obligation 46,413 52,101 13,506 6,324 13,062 10,479 Expected return on assets (60,078 ) (68,103 ) (18,315 ) (8,175 ) (18,666 ) (13,704 ) Amortization of loss 40,692 44,853 11,172 6,039 9,714 9,792 Net pension cost $47,010 $54,648 $12,309 $6,735 $9,045 $12,438
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $390.1 million to its qualified pension plans in 2016. As of September 30, 2016 , Entergy had contributed $307.6 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 2016 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2016 pension contributions $83,001 $84,422 $19,968 $10,709 $15,920 $20,498 Pension contributions made through September 2016 $65,882 $67,116 $15,981 $8,456 $12,649 $16,120 Remaining estimated pension contributions to be made in 2016 $17,119 $17,306 $3,987 $2,253 $3,271 $4,378
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 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,934 $5,607 $1,158 $468 $1,194 $1,002 Interest cost on APBO 6,972 9,780 2,127 1,344 3,117 1,587 Expected return on assets (13,392 ) — (4,137 ) (3,462 ) (7,182 ) (2,442 ) Amortization of prior service credit (4,104 ) (5,841 ) (702 ) (558 ) (2,043 ) (1,179 ) Amortization of loss 3,192 2,196 669 111 1,611 861 Net other postretirement benefit cost ($4,398 ) $11,742 ($885 ) ($2,097 ) ($3,303 ) ($171 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,217 $7,422 $1,521 $615 $1,500 $1,410 Interest cost on APBO 9,390 12,234 2,577 1,956 4,026 1,884 Expected return on assets (14,394 ) — (4,626 ) (3,603 ) (7,764 ) (2,733 ) Amortization of prior service credit (1,830 ) (5,601 ) (687 ) (531 ) (2,043 ) (1,098 ) Amortization of loss 4,017 5,340 645 354 2,055 900 Net other postretirement benefit cost $2,400 $19,395 ($570 ) ($1,209 ) ($2,226 ) $363
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 in the third quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Third quarter 2016 $105 $58 $60 $16 $126 Third quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Nine months ended September 30, 2016 $317 $176 $179 $48 $380 Nine months ended September 30, 2015 $339 $204 $177 $48 $447
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 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $15,543 $21,147 $4,686 $1,968 $4,248 $4,698 Interest cost on projected benefit obligation 39,165 44,610 11,433 5,442 10,671 8,976 Expected return on assets (59,316 ) (66,288 ) (17,943 ) (8,061 ) (18,186 ) (13,377 ) Amortization of loss 32,808 35,838 8,955 4,845 7,020 7,812 Net pension cost $28,200 $35,307 $7,131 $4,194 $3,753 $8,109 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $19,983 $25,797 $5,946 $2,547 $4,935 $5,871 Interest cost on projected benefit obligation 46,413 52,101 13,506 6,324 13,062 10,479 Expected return on assets (60,078 ) (68,103 ) (18,315 ) (8,175 ) (18,666 ) (13,704 ) Amortization of loss 40,692 44,853 11,172 6,039 9,714 9,792 Net pension cost $47,010 $54,648 $12,309 $6,735 $9,045 $12,438
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $390.1 million to its qualified pension plans in 2016. As of September 30, 2016 , Entergy had contributed $307.6 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 2016 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2016 pension contributions $83,001 $84,422 $19,968 $10,709 $15,920 $20,498 Pension contributions made through September 2016 $65,882 $67,116 $15,981 $8,456 $12,649 $16,120 Remaining estimated pension contributions to be made in 2016 $17,119 $17,306 $3,987 $2,253 $3,271 $4,378
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 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $2,934 $5,607 $1,158 $468 $1,194 $1,002 Interest cost on APBO 6,972 9,780 2,127 1,344 3,117 1,587 Expected return on assets (13,392 ) — (4,137 ) (3,462 ) (7,182 ) (2,442 ) Amortization of prior service credit (4,104 ) (5,841 ) (702 ) (558 ) (2,043 ) (1,179 ) Amortization of loss 3,192 2,196 669 111 1,611 861 Net other postretirement benefit cost ($4,398 ) $11,742 ($885 ) ($2,097 ) ($3,303 ) ($171 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,217 $7,422 $1,521 $615 $1,500 $1,410 Interest cost on APBO 9,390 12,234 2,577 1,956 4,026 1,884 Expected return on assets (14,394 ) — (4,626 ) (3,603 ) (7,764 ) (2,733 ) Amortization of prior service credit (1,830 ) (5,601 ) (687 ) (531 ) (2,043 ) (1,098 ) Amortization of loss 4,017 5,340 645 354 2,055 900 Net other postretirement benefit cost $2,400 $19,395 ($570 ) ($1,209 ) ($2,226 ) $363

Business Segment Information (T

Business Segment Information (Tables)	9 Months Ended
	Sep. 30, 2016
Segment Financial Information	Entergy’s segment financial information for the third quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,649,392 $475,345 $— ($34 ) $3,124,703 Income taxes $255,603 $6,115 ($3,812 ) $— $257,906 Consolidated net income (loss) $447,782 $8,221 ($30,901 ) ($31,898 ) $393,204 2015 Operating revenues $2,849,681 $521,746 $— ($21 ) $3,371,406 Income taxes $198,945 ($554,513 ) ($12,097 ) $— ($367,665 ) Consolidated net income (loss) $364,265 ($1,031,410 ) ($19,190 ) ($31,898 ) ($718,233 ) Entergy’s segment financial information for the nine months ended September 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $6,855,664 $1,341,534 $— ($80 ) $8,197,118 Income taxes $359,653 ($176,626 ) ($34,148 ) $— $148,879 Consolidated net income (loss) $1,027,751 $338,651 ($69,672 ) ($95,695 ) $1,201,035 Total assets as of September 30, 2016 $40,542,593 $9,100,779 $1,339,879 ($3,245,070 ) $47,738,181 2015 Operating revenues $7,401,136 $1,603,643 $— ($51 ) $9,004,728 Income taxes $407,993 ($487,622 ) ($37,783 ) $— ($117,412 ) Consolidated net income (loss) $796,051 ($911,524 ) ($50,415 ) ($95,695 ) ($261,583 ) Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.

Risk Management And Fair Valu29

Risk Management And Fair Values (Tables)	9 Months Ended
	Sep. 30, 2016
Fair Values Of Derivative Instruments	The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $67 ($17) $50 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($5) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $1 ($1) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $42 ($17) $25 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($1) $5 Entergy Wholesale Commodities FTRs Prepayments and other $32 ($1) $31 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $34 ($34) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($3) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2015 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $173 ($34) $139 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $17 ($2) $15 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $14 ($14) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $54 ($13) $41 Entergy Wholesale Commodities FTRs Prepayments and other $24 ($1) $23 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $38 ($32) $6 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 Utility
Derivative Instruments Designated As Cash Flow Hedges On Consolidated Statements Of Income	The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $70 Competitive businesses operating revenues $37 2015 Electricity swaps and options $49 Competitive businesses operating revenues $86 (a) Before taxes of $13 million and $30 million for the three months ended September 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $156 Competitive businesses operating revenues $237 2015 Electricity swaps and options $154 Competitive businesses operating revenues $177 (a) Before taxes of $83 million and $61 million for the nine months ended September 30, 2016 and 2015, 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 statements of operations for the three months ended September 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $25 FTRs $— Purchased power expense (b) $37 Electricity swaps and options ($9) (c) Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) FTRs $— Purchased power expense (b) $51 Electricity swaps and options $— (c) Competitive business operating revenues ($3) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the nine months ended September 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($5) FTRs $— Purchased power expense (b) $96 Electricity swaps and options $6 (c) Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($29) FTRs $— Purchased power expense (b) $130 Electricity swaps and options $1 (c) Competitive business operating revenues ($42) (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 FTRs 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 FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in AOCI 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, 2016 and December 31, 2015 . The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect their placement within the fair value hierarchy levels. 2016 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,206 $— $— $1,206 Decommissioning trust funds (a): Equity securities 451 — — 451 Debt securities 1,016 1,275 — 2,291 Common trusts (b) 2,929 Power contracts — — 95 95 Securitization recovery trust account 54 — — 54 Escrow accounts 433 — — 433 FTRs — — 31 31 $3,160 $1,275 $126 $7,490 Liabilities: Gas hedge contracts $1 $— $— $1 2015 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,287 $— $— $1,287 Decommissioning trust funds (a): Equity securities 468 — — 468 Debt securities 1,061 1,094 — 2,155 Common trusts (b) 2,727 Power contracts — — 195 195 Securitization recovery trust account 50 — — 50 Escrow accounts 425 — — 425 FTRs — — 23 23 $3,291 $1,094 $218 $7,330 Liabilities: Power contracts $— $— $6 $6 Gas hedge contracts 9 — — 9 $9 $— $6 $15
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, 2016 and 2015 : 2016 2015 Power Contracts FTRs Power Contracts FTRs (In Millions) Balance as of July 1, $66 $46 $204 $67 Total gains (losses) for the period (a) Included in earnings 6 — (2 ) — Included in OCI 70 — 49 — Included as a regulatory liability/asset — 22 — 31 Settlements (47 ) (37 ) (88 ) (51 ) Balance as of September 30, $95 $31 $163 $47 (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 million for the three months ended September 30, 2016 and $12 million for the three months ended September 30, 2015. 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, 2016 and 2015 : 2016 2015 Power Contracts FTRs Power Contracts FTRs (In Millions) Balance as of January 1, $189 $23 $215 $47 Total gains (losses) for the period (a) Included in earnings (3 ) — (15 ) (1 ) Included in OCI 156 — 154 — Included as a regulatory liability/asset — 49 — 51 Issuances of FTRs — 55 — 80 Purchases — — 14 — Settlements (247 ) (96 ) (205 ) (130 ) Balance as of September 30, $95 $31 $163 $47 (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 million for the nine months ended September 30, 2016 and $5 million for the nine months ended September 30, 2015.
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, 2016 : Transaction Type Fair Value as of September 30, 2016 Significant Unobservable Inputs Range from Average % Effect on Fair Value (In Millions) (In Millions) Power contracts - electricity swaps $90 Unit contingent discount +/- 4% $7 Power contracts - electricity options $5 Implied volatility +/- 9% $4
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, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $8.1 Entergy Arkansas FTRs Prepayments and other $12.4 Entergy Louisiana FTRs Prepayments and other $4.0 Entergy Mississippi FTRs Prepayments and other $1.6 Entergy New Orleans FTRs Prepayments and other $5.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $0.4 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2015 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $7.9 Entergy Arkansas FTRs Prepayments and other $8.5 Entergy Louisiana FTRs Prepayments and other $2.4 Entergy Mississippi FTRs Prepayments and other $1.5 Entergy New Orleans FTRs Prepayments and other $2.2 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.3 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 Entergy New Orleans (a) No cash collateral or letters of credit were required to be posted for FTR exposure as of September 30, 2016 and December 31, 2015, respectively.
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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $5.3 (a) Entergy Mississippi FTRs Purchased power expense $7.1 (b) Entergy Arkansas FTRs Purchased power expense $20.4 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $0.9 (b) Entergy New Orleans FTRs Purchased power expense $1.8 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($10.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans FTRs Purchased power expense $13.9 (b) Entergy Arkansas FTRs Purchased power expense $17.9 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $1.5 (b) Entergy New Orleans FTRs Purchased power expense $10.9 (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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.5) (a) Entergy New Orleans FTRs Purchased power expense $20.3 (b) Entergy Arkansas FTRs Purchased power expense $52.5 (b) Entergy Louisiana FTRs Purchased power expense $11.1 (b) Entergy Mississippi FTRs Purchased power expense $2.8 (b) Entergy New Orleans FTRs Purchased power expense $8.7 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($23.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.3) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy New Orleans FTRs Purchased power expense $48.6 (b) Entergy Arkansas FTRs Purchased power expense $49.7 (b) Entergy Louisiana FTRs Purchased power expense $13.9 (b) Entergy Mississippi FTRs Purchased power expense $7.5 (b) Entergy New Orleans FTRs Purchased power expense $10.7 (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 FTRs 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 FTRs 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 2016 Level 1 Level 2 Level 3 Total (In Millions) Assets: Decommissioning trust funds (a): Equity securities $3.7 $— $— $3.7 Debt securities 103.1 215.8 — 318.9 Common trusts (b) 501.2 Securitization recovery trust account 7.7 — — 7.7 Escrow accounts 7.1 — — 7.1 FTRs — — 8.1 8.1 $121.6 $215.8 $8.1 $846.7 2015 Level 1 Level 2 Level 3 Total (In Millions) Assets: Decommissioning trust funds (a): Equity securities $3.0 $— $— $3.0 Debt securities 110.5 193.4 — 303.9 Common trusts (b) 464.4 Securitization recovery trust account 4.2 — — 4.2 Escrow accounts 12.2 — — 12.2 FTRs — — 7.9 7.9 $129.9 $193.4 $7.9 $795.6
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, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of July 1, $14.0 $16.2 $5.6 $2.0 $8.0 Gains (losses) included as a regulatory liability/asset 1.2 16.6 5.1 0.5 (1.1 ) Settlements (7.1 ) (20.4 ) (6.7 ) (0.9 ) (1.8 ) Balance as of September 30, $8.1 $12.4 $4.0 $1.6 $5.1 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, 2015 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, $9.1 $37.3 $4.9 $6.7 $7.9 Gains (losses) included as a regulatory liability/asset 16.5 3.0 6.1 (1.2 ) 7.3 Settlements (13.9 ) (17.9 ) (6.7 ) (1.5 ) (10.9 ) Balance as of September 30, $11.7 $22.4 $4.3 $4.0 $4.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $7.9 $8.5 $2.4 $1.5 $2.2 Issuances of FTRs 18.8 18.1 5.9 2.8 9.3 Gains (losses) included as a regulatory liability/asset 1.7 38.3 6.8 0.1 2.3 Settlements (20.3 ) (52.5 ) (11.1 ) (2.8 ) (8.7 ) Balance as of September 30, $8.1 $12.4 $4.0 $1.6 $5.1 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, 2015 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $0.7 $25.5 $3.4 $4.1 $12.3 Issuances of FTRs 7.0 48.3 5.4 7.3 11.4 Gains (losses) included as a regulatory liability/asset 52.6 (1.7 ) 9.4 0.1 (8.7 ) Settlements (48.6 ) (49.7 ) (13.9 ) (7.5 ) (10.7 ) Balance as of September 30, $11.7 $22.4 $4.3 $4.0 $4.3
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, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $8.1 Entergy Arkansas FTRs Prepayments and other $12.4 Entergy Louisiana FTRs Prepayments and other $4.0 Entergy Mississippi FTRs Prepayments and other $1.6 Entergy New Orleans FTRs Prepayments and other $5.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $0.4 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2015 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $7.9 Entergy Arkansas FTRs Prepayments and other $8.5 Entergy Louisiana FTRs Prepayments and other $2.4 Entergy Mississippi FTRs Prepayments and other $1.5 Entergy New Orleans FTRs Prepayments and other $2.2 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.3 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 Entergy New Orleans (a) No cash collateral or letters of credit were required to be posted for FTR exposure as of September 30, 2016 and December 31, 2015, respectively.
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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $5.3 (a) Entergy Mississippi FTRs Purchased power expense $7.1 (b) Entergy Arkansas FTRs Purchased power expense $20.4 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $0.9 (b) Entergy New Orleans FTRs Purchased power expense $1.8 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($10.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans FTRs Purchased power expense $13.9 (b) Entergy Arkansas FTRs Purchased power expense $17.9 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $1.5 (b) Entergy New Orleans FTRs Purchased power expense $10.9 (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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.5) (a) Entergy New Orleans FTRs Purchased power expense $20.3 (b) Entergy Arkansas FTRs Purchased power expense $52.5 (b) Entergy Louisiana FTRs Purchased power expense $11.1 (b) Entergy Mississippi FTRs Purchased power expense $2.8 (b) Entergy New Orleans FTRs Purchased power expense $8.7 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($23.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.3) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy New Orleans FTRs Purchased power expense $48.6 (b) Entergy Arkansas FTRs Purchased power expense $49.7 (b) Entergy Louisiana FTRs Purchased power expense $13.9 (b) Entergy Mississippi FTRs Purchased power expense $7.5 (b) Entergy New Orleans FTRs Purchased power expense $10.7 (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 FTRs 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 FTRs 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 2016 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $57.6 $— $— $57.6 Decommissioning trust funds (a): Equity securities 5.7 — — 5.7 Debt securities 131.5 308.6 — 440.1 Common trusts (b) 679.0 Escrow accounts 305.5 — — 305.5 Securitization recovery trust account 9.8 — — 9.8 FTRs — — 12.4 12.4 $510.1 $308.6 $12.4 $1,510.1 Liabilities: Gas hedge contracts $0.4 $— $— $0.4 2015 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $34.8 $— $— $34.8 Decommissioning trust funds (a): Equity securities 7.1 — — 7.1 Debt securities 161.1 248.8 — 409.9 Common trusts (b) 625.3 Escrow accounts 290.4 — — 290.4 Securitization recovery trust account 3.2 — — 3.2 FTRs — — 8.5 8.5 $496.6 $248.8 $8.5 $1,379.2 Liabilities: Gas hedge contracts $7.0 $— $— $7.0
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, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of July 1, $14.0 $16.2 $5.6 $2.0 $8.0 Gains (losses) included as a regulatory liability/asset 1.2 16.6 5.1 0.5 (1.1 ) Settlements (7.1 ) (20.4 ) (6.7 ) (0.9 ) (1.8 ) Balance as of September 30, $8.1 $12.4 $4.0 $1.6 $5.1 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, 2015 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, $9.1 $37.3 $4.9 $6.7 $7.9 Gains (losses) included as a regulatory liability/asset 16.5 3.0 6.1 (1.2 ) 7.3 Settlements (13.9 ) (17.9 ) (6.7 ) (1.5 ) (10.9 ) Balance as of September 30, $11.7 $22.4 $4.3 $4.0 $4.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $7.9 $8.5 $2.4 $1.5 $2.2 Issuances of FTRs 18.8 18.1 5.9 2.8 9.3 Gains (losses) included as a regulatory liability/asset 1.7 38.3 6.8 0.1 2.3 Settlements (20.3 ) (52.5 ) (11.1 ) (2.8 ) (8.7 ) Balance as of September 30, $8.1 $12.4 $4.0 $1.6 $5.1 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, 2015 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $0.7 $25.5 $3.4 $4.1 $12.3 Issuances of FTRs 7.0 48.3 5.4 7.3 11.4 Gains (losses) included as a regulatory liability/asset 52.6 (1.7 ) 9.4 0.1 (8.7 ) Settlements (48.6 ) (49.7 ) (13.9 ) (7.5 ) (10.7 ) Balance as of September 30, $11.7 $22.4 $4.3 $4.0 $4.3
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, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $8.1 Entergy Arkansas FTRs Prepayments and other $12.4 Entergy Louisiana FTRs Prepayments and other $4.0 Entergy Mississippi FTRs Prepayments and other $1.6 Entergy New Orleans FTRs Prepayments and other $5.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $0.4 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2015 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $7.9 Entergy Arkansas FTRs Prepayments and other $8.5 Entergy Louisiana FTRs Prepayments and other $2.4 Entergy Mississippi FTRs Prepayments and other $1.5 Entergy New Orleans FTRs Prepayments and other $2.2 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.3 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 Entergy New Orleans (a) No cash collateral or letters of credit were required to be posted for FTR exposure as of September 30, 2016 and December 31, 2015, respectively.
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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $5.3 (a) Entergy Mississippi FTRs Purchased power expense $7.1 (b) Entergy Arkansas FTRs Purchased power expense $20.4 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $0.9 (b) Entergy New Orleans FTRs Purchased power expense $1.8 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($10.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans FTRs Purchased power expense $13.9 (b) Entergy Arkansas FTRs Purchased power expense $17.9 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $1.5 (b) Entergy New Orleans FTRs Purchased power expense $10.9 (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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.5) (a) Entergy New Orleans FTRs Purchased power expense $20.3 (b) Entergy Arkansas FTRs Purchased power expense $52.5 (b) Entergy Louisiana FTRs Purchased power expense $11.1 (b) Entergy Mississippi FTRs Purchased power expense $2.8 (b) Entergy New Orleans FTRs Purchased power expense $8.7 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($23.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.3) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy New Orleans FTRs Purchased power expense $48.6 (b) Entergy Arkansas FTRs Purchased power expense $49.7 (b) Entergy Louisiana FTRs Purchased power expense $13.9 (b) Entergy Mississippi FTRs Purchased power expense $7.5 (b) Entergy New Orleans FTRs Purchased power expense $10.7 (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 FTRs 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 FTRs 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 2016 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $307.3 $— $— $307.3 Escrow accounts 31.8 — — 31.8 FTRs — — 4.0 4.0 $339.1 $— $4.0 $343.1 Liabilities: Gas hedge contracts $0.1 $— $— $0.1 2015 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $144.2 $— $— $144.2 Escrow accounts 41.7 — — 41.7 FTRs — — 2.4 2.4 $185.9 $— $2.4 $188.3 Liabilities: Gas hedge contracts $1.3 $— $— $1.3
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of July 1, $14.0 $16.2 $5.6 $2.0 $8.0 Gains (losses) included as a regulatory liability/asset 1.2 16.6 5.1 0.5 (1.1 ) Settlements (7.1 ) (20.4 ) (6.7 ) (0.9 ) (1.8 ) Balance as of September 30, $8.1 $12.4 $4.0 $1.6 $5.1 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, 2015 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, $9.1 $37.3 $4.9 $6.7 $7.9 Gains (losses) included as a regulatory liability/asset 16.5 3.0 6.1 (1.2 ) 7.3 Settlements (13.9 ) (17.9 ) (6.7 ) (1.5 ) (10.9 ) Balance as of September 30, $11.7 $22.4 $4.3 $4.0 $4.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $7.9 $8.5 $2.4 $1.5 $2.2 Issuances of FTRs 18.8 18.1 5.9 2.8 9.3 Gains (losses) included as a regulatory liability/asset 1.7 38.3 6.8 0.1 2.3 Settlements (20.3 ) (52.5 ) (11.1 ) (2.8 ) (8.7 ) Balance as of September 30, $8.1 $12.4 $4.0 $1.6 $5.1 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, 2015 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $0.7 $25.5 $3.4 $4.1 $12.3 Issuances of FTRs 7.0 48.3 5.4 7.3 11.4 Gains (losses) included as a regulatory liability/asset 52.6 (1.7 ) 9.4 0.1 (8.7 ) Settlements (48.6 ) (49.7 ) (13.9 ) (7.5 ) (10.7 ) Balance as of September 30, $11.7 $22.4 $4.3 $4.0 $4.3
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, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $8.1 Entergy Arkansas FTRs Prepayments and other $12.4 Entergy Louisiana FTRs Prepayments and other $4.0 Entergy Mississippi FTRs Prepayments and other $1.6 Entergy New Orleans FTRs Prepayments and other $5.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $0.4 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2015 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $7.9 Entergy Arkansas FTRs Prepayments and other $8.5 Entergy Louisiana FTRs Prepayments and other $2.4 Entergy Mississippi FTRs Prepayments and other $1.5 Entergy New Orleans FTRs Prepayments and other $2.2 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.3 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 Entergy New Orleans (a) No cash collateral or letters of credit were required to be posted for FTR exposure as of September 30, 2016 and December 31, 2015, respectively.
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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $5.3 (a) Entergy Mississippi FTRs Purchased power expense $7.1 (b) Entergy Arkansas FTRs Purchased power expense $20.4 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $0.9 (b) Entergy New Orleans FTRs Purchased power expense $1.8 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($10.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans FTRs Purchased power expense $13.9 (b) Entergy Arkansas FTRs Purchased power expense $17.9 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $1.5 (b) Entergy New Orleans FTRs Purchased power expense $10.9 (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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.5) (a) Entergy New Orleans FTRs Purchased power expense $20.3 (b) Entergy Arkansas FTRs Purchased power expense $52.5 (b) Entergy Louisiana FTRs Purchased power expense $11.1 (b) Entergy Mississippi FTRs Purchased power expense $2.8 (b) Entergy New Orleans FTRs Purchased power expense $8.7 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($23.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.3) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy New Orleans FTRs Purchased power expense $48.6 (b) Entergy Arkansas FTRs Purchased power expense $49.7 (b) Entergy Louisiana FTRs Purchased power expense $13.9 (b) Entergy Mississippi FTRs Purchased power expense $7.5 (b) Entergy New Orleans FTRs Purchased power expense $10.7 (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 FTRs 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 FTRs 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 2016 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $37.2 $— $— $37.2 Securitization recovery trust account 5.1 — — 5.1 Escrow accounts 88.4 — — 88.4 FTRs — — 1.6 1.6 $130.7 $— $1.6 $132.3 2015 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $87.8 $— $— $87.8 Securitization recovery trust account 4.6 — — 4.6 Escrow accounts 81.0 — — 81.0 FTRs — — 1.5 1.5 $173.4 $— $1.5 $174.9 Liabilities: Gas hedge contracts $0.5 $— $— $0.5
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of July 1, $14.0 $16.2 $5.6 $2.0 $8.0 Gains (losses) included as a regulatory liability/asset 1.2 16.6 5.1 0.5 (1.1 ) Settlements (7.1 ) (20.4 ) (6.7 ) (0.9 ) (1.8 ) Balance as of September 30, $8.1 $12.4 $4.0 $1.6 $5.1 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, 2015 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, $9.1 $37.3 $4.9 $6.7 $7.9 Gains (losses) included as a regulatory liability/asset 16.5 3.0 6.1 (1.2 ) 7.3 Settlements (13.9 ) (17.9 ) (6.7 ) (1.5 ) (10.9 ) Balance as of September 30, $11.7 $22.4 $4.3 $4.0 $4.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $7.9 $8.5 $2.4 $1.5 $2.2 Issuances of FTRs 18.8 18.1 5.9 2.8 9.3 Gains (losses) included as a regulatory liability/asset 1.7 38.3 6.8 0.1 2.3 Settlements (20.3 ) (52.5 ) (11.1 ) (2.8 ) (8.7 ) Balance as of September 30, $8.1 $12.4 $4.0 $1.6 $5.1 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, 2015 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $0.7 $25.5 $3.4 $4.1 $12.3 Issuances of FTRs 7.0 48.3 5.4 7.3 11.4 Gains (losses) included as a regulatory liability/asset 52.6 (1.7 ) 9.4 0.1 (8.7 ) Settlements (48.6 ) (49.7 ) (13.9 ) (7.5 ) (10.7 ) Balance as of September 30, $11.7 $22.4 $4.3 $4.0 $4.3
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, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $8.1 Entergy Arkansas FTRs Prepayments and other $12.4 Entergy Louisiana FTRs Prepayments and other $4.0 Entergy Mississippi FTRs Prepayments and other $1.6 Entergy New Orleans FTRs Prepayments and other $5.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $0.4 Entergy Louisiana Natural gas swaps Other current liabilities $0.1 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2015 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $7.9 Entergy Arkansas FTRs Prepayments and other $8.5 Entergy Louisiana FTRs Prepayments and other $2.4 Entergy Mississippi FTRs Prepayments and other $1.5 Entergy New Orleans FTRs Prepayments and other $2.2 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.3 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 Entergy New Orleans (a) No cash collateral or letters of credit were required to be posted for FTR exposure as of September 30, 2016 and December 31, 2015, respectively.
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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $5.3 (a) Entergy Mississippi FTRs Purchased power expense $7.1 (b) Entergy Arkansas FTRs Purchased power expense $20.4 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $0.9 (b) Entergy New Orleans FTRs Purchased power expense $1.8 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($10.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans FTRs Purchased power expense $13.9 (b) Entergy Arkansas FTRs Purchased power expense $17.9 (b) Entergy Louisiana FTRs Purchased power expense $6.7 (b) Entergy Mississippi FTRs Purchased power expense $1.5 (b) Entergy New Orleans FTRs Purchased power expense $10.9 (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, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.5) (a) Entergy New Orleans FTRs Purchased power expense $20.3 (b) Entergy Arkansas FTRs Purchased power expense $52.5 (b) Entergy Louisiana FTRs Purchased power expense $11.1 (b) Entergy Mississippi FTRs Purchased power expense $2.8 (b) Entergy New Orleans FTRs Purchased power expense $8.7 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($23.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.3) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy New Orleans FTRs Purchased power expense $48.6 (b) Entergy Arkansas FTRs Purchased power expense $49.7 (b) Entergy Louisiana FTRs Purchased power expense $13.9 (b) Entergy Mississippi FTRs Purchased power expense $7.5 (b) Entergy New Orleans FTRs Purchased power expense $10.7 (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 FTRs 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 FTRs 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 2016 Level 1 Level 2 Level 3 Total (In Millions) Assets : Securitization recovery trust account $31.4 $— $— $31.4 FTRs — — 5.1 5.1 $31.4 $— $5.1 $36.5 2015 Level 1 Level 2 Level 3 Total (In Millions) Assets : Securitization recovery trust account $38.2 $— $— $38.2 FTRs — — 2.2 2.2 $38.2 $— $2.2 $40.4
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of July 1, $14.0 $16.2 $5.6 $2.0 $8.0 Gains (losses) included as a regulatory liability/asset 1.2 16.6 5.1 0.5 (1.1 ) Settlements (7.1 ) (20.4 ) (6.7 ) (0.9 ) (1.8 ) Balance as of September 30, $8.1 $12.4 $4.0 $1.6 $5.1 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, 2015 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of July 1, $9.1 $37.3 $4.9 $6.7 $7.9 Gains (losses) included as a regulatory liability/asset 16.5 3.0 6.1 (1.2 ) 7.3 Settlements (13.9 ) (17.9 ) (6.7 ) (1.5 ) (10.9 ) Balance as of September 30, $11.7 $22.4 $4.3 $4.0 $4.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $7.9 $8.5 $2.4 $1.5 $2.2 Issuances of FTRs 18.8 18.1 5.9 2.8 9.3 Gains (losses) included as a regulatory liability/asset 1.7 38.3 6.8 0.1 2.3 Settlements (20.3 ) (52.5 ) (11.1 ) (2.8 ) (8.7 ) Balance as of September 30, $8.1 $12.4 $4.0 $1.6 $5.1 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, 2015 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $0.7 $25.5 $3.4 $4.1 $12.3 Issuances of FTRs 7.0 48.3 5.4 7.3 11.4 Gains (losses) included as a regulatory liability/asset 52.6 (1.7 ) 9.4 0.1 (8.7 ) Settlements (48.6 ) (49.7 ) (13.9 ) (7.5 ) (10.7 ) Balance as of September 30, $11.7 $22.4 $4.3 $4.0 $4.3
System Energy [Member]
Assets and liabilities at fair value on a recurring basis	System Energy 2016 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $190.2 $— $— $190.2 Decommissioning trust funds (a): Equity securities 1.2 — — 1.2 Debt securities 246.5 62.1 — 308.6 Common trusts (b) 455.1 $437.9 $62.1 $— $955.1 2015 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $222.0 $— $— $222.0 Decommissioning trust funds (a): Equity securities 1.8 — — 1.8 Debt securities 218.6 59.2 — 277.8 Common trusts (b) 421.9 $442.4 $59.2 $— $923.5

Decommissioning Trust Funds (Ta

Decommissioning Trust Funds (Tables)	9 Months Ended
	Sep. 30, 2016
Securities Held	The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,380 $1,568 $1 Debt Securities 2,291 94 2 Total $5,671 $1,662 $3 Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2015 Equity Securities $3,195 $1,396 $2 Debt Securities 2,155 41 17 Total $5,350 $1,437 $19
Available For Sale Securities Continuous Unrealized Loss Position Fair Value	The fair value and gross unrealized losses of available-for-sale equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $13 $1 $266 $1 More than 12 months — — 23 1 Total $13 $1 $289 $2 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $54 $2 $1,031 $15 More than 12 months 1 — 61 2 Total $55 $2 $1,092 $17
Fair Value Of Debt Securities By Contractual Maturities	The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $102 $77 1 year - 5 years 812 857 5 years - 10 years 743 704 10 years - 15 years 128 124 15 years - 20 years 62 50 20 years+ 444 343 Total $2,291 $2,155
Entergy Arkansas [Member]
Securities Held	Entergy Arkansas holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $504.9 $263.4 $— Debt Securities 318.9 10.8 0.3 Total $823.8 $274.2 $0.3 2015 Equity Securities $467.4 $234.4 $0.2 Debt Securities 303.9 4.1 2.2 Total $771.3 $238.5 $2.4
Available For Sale Securities Continuous Unrealized Loss Position Fair Value	The fair value and gross unrealized losses of available-for-sale equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $0.9 $— $32.5 $0.3 More than 12 months — — — — Total $0.9 $— $32.5 $0.3 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $7.8 $0.2 $111.4 $1.7 More than 12 months — — 18.5 0.5 Total $7.8 $0.2 $129.9 $2.2
Fair Value Of Debt Securities By Contractual Maturities	The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $8.8 $1.8 1 year - 5 years 123.5 145.2 5 years - 10 years 166.1 138.5 10 years - 15 years 9.5 2.4 15 years - 20 years 1.1 2.0 20 years+ 9.9 14.0 Total $318.9 $303.9
Entergy Louisiana [Member]
Securities Held	Entergy Louisiana holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $684.7 $322.9 $— Debt Securities 440.1 21.4 0.4 Total $1,124.8 $344.3 $0.4 2015 Equity Securities $632.4 $283.7 $0.2 Debt Securities 409.9 13.2 2.4 Total $1,042.3 $296.9 $2.6
Available For Sale Securities Continuous Unrealized Loss Position Fair Value	The fair value and gross unrealized losses of available-for-sale equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $2.3 $— $32.5 $0.2 More than 12 months — — 6.5 0.2 Total $2.3 $— $39.0 $0.4 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $9.4 $0.2 $124.0 $2.0 More than 12 months — — 7.4 0.4 Total $9.4 $0.2 $131.4 $2.4
Fair Value Of Debt Securities By Contractual Maturities	The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $25.0 $27.1 1 year - 5 years 102.3 124.0 5 years - 10 years 121.5 114.3 10 years - 15 years 51.0 39.3 15 years - 20 years 31.1 26.5 20 years+ 109.2 78.7 Total $440.1 $409.9
System Energy [Member]
Securities Held	System Energy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of September 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $456.3 $205.5 $0.1 Debt Securities 308.6 6.7 0.3 Total $764.9 $212.2 $0.4 2015 Equity Securities $423.7 $179.2 $0.3 Debt Securities 277.8 2.2 2.3 Total $701.5 $181.4 $2.6
Available For Sale Securities Continuous Unrealized Loss Position Fair Value	The fair value and gross unrealized losses of available-for-sale equity and 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $0.8 $— $81.4 $0.2 More than 12 months — 0.1 1.0 0.1 Total $0.8 $0.1 $82.4 $0.3 The fair value and gross unrealized losses of available-for-sale equity and 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 December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8.3 $0.2 $200.4 $2.2 More than 12 months 0.9 0.1 5.0 0.1 Total $9.2 $0.3 $205.4 $2.3
Fair Value Of Debt Securities By Contractual Maturities	The fair value of debt securities, summarized by contractual maturities, as of September 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $3.0 $2.0 1 year - 5 years 192.6 181.2 5 years - 10 years 76.2 63.0 10 years - 15 years 3.5 4.4 15 years - 20 years 1.5 1.6 20 years+ 31.8 25.6 Total $308.6 $277.8

Commitments and Contingencies C

Commitments and Contingencies Commitments And Contingencies (Narrative) (Details) (Details)	1 Months Ended									9 Months Ended	12 Months Ended
	Oct. 31, 2016USD ($)	Sep. 30, 2016USD ($)MW	Aug. 31, 2016USD ($)	Jul. 31, 2016USD ($)	Jun. 30, 2016USD ($)	May 31, 2016USD ($)	Apr. 30, 2016USD ($)	Dec. 31, 2015USD ($)	Oct. 31, 2015USD ($)	Sep. 30, 2016USD ($)MW	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Regulatory Assets [Line Items]
Other Receivables		$ 227,278,000						$ 178,364,000		$ 227,278,000		$ 178,364,000
Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Other Receivables		8,328,000						8,276,000		8,328,000		8,276,000
Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Other Receivables		81,260,000						84,216,000		81,260,000		84,216,000
Entergy Arkansas [Member] | ANO [Member]
Regulatory Assets [Line Items]
Incremental NRC Inspection Costs												53,000,000
Litigation Settlement, Amount				$ 31,000,000
Damages awarded for previously capitalized costs		6,000,000
Damages awarded for previously recorded operation and maintenance		6,000,000
Plant balance reduction		6,000,000
Previously recorded nuclear fuel expense		$ 19,000,000
NRC inspection costs excluding remediation and response costs										$ 37,000,000
Entergy Arkansas [Member] | Subsequent Event [Member] | ANO [Member]
Regulatory Assets [Line Items]
Expected NRC inspection costs excluding remediation and response costs											$ 50,000,000
Entergy Wholesale Commodities [Member] | Pilgrim [Member]
Regulatory Assets [Line Items]
Capacity Supply Obligations in ISO New England | MW		677								677
NRC inspection costs										$ 20,000,000
Entergy Wholesale Commodities [Member] | Indian Point 3 and FitzPatrick [Domain]
Regulatory Assets [Line Items]
Litigation Settlement, Amount								81,000,000
Entergy Wholesale Commodities [Member] | Indian Point 3 [Domain]
Regulatory Assets [Line Items]
Damages awarded for previously capitalized costs								45,000,000
Damages awarded for previously recorded operation and maintenance								2,000,000
Reduction of previously recorded deprecation expense								8,000,000
Plant balance reduction								37,000,000
Entergy Wholesale Commodities [Member] | Fitzpatrick [Member]
Regulatory Assets [Line Items]
Damages awarded for previously capitalized costs								32,000,000
Damages awarded for previously recorded operation and maintenance								2,000,000
Plant balance reduction								11,000,000
Carrying Value of Nuclear Plant								0				0
Reduction to operation and maintenance expense								21,000,000
Entergy Wholesale Commodities [Member] | Vermont Yankee [Member]
Regulatory Assets [Line Items]
Litigation Settlement, Amount						$ 19,000,000
Damages awarded for previously capitalized costs					$ 15,000,000
Damages awarded for previously recorded operation and maintenance					4,000,000
Reduction of previously recorded deprecation expense					2,000,000
Reduction to operation and maintenance expense					13,000,000
Entergy Wholesale Commodities [Member] | Palisades [Member]
Regulatory Assets [Line Items]
Litigation Settlement, Amount		$ 14,000,000							$ 21,000,000
Entergy Wholesale Commodities [Member] | Minimum [Member] | Pilgrim [Member]
Regulatory Assets [Line Items]
Expected NRC inspection costs		45,000,000								45,000,000
Entergy Wholesale Commodities [Member] | Maximum [Member] | Pilgrim [Member]
Regulatory Assets [Line Items]
Expected NRC inspection costs		60,000,000								60,000,000
Entergy Wholesale Commodities [Member] | Subsequent Event [Member] | Pilgrim [Member]
Regulatory Assets [Line Items]
Expected NRC inspection costs											$ 30,000,000
Entergy Wholesale Commodities [Member] | Subsequent Event [Member] | Indian Point 2 [Domain]
Regulatory Assets [Line Items]
Litigation Settlement, Amount	$ 34,000,000
Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Other Receivables		108,213,000						56,793,000		108,213,000		56,793,000
Entergy Louisiana [Member] | River Bend [Member]
Regulatory Assets [Line Items]
Litigation Settlement, Amount		5,000,000					$ 42,000,000
Damages awarded for previously capitalized costs							17,000,000
Damages awarded for previously recorded operation and maintenance							2,000,000
Reduction of previously recorded deprecation expense							3,000,000
Plant balance reduction							14,000,000
Previously recorded nuclear fuel expense							$ 23,000,000
Entergy Louisiana [Member] | Waterford Three [Member]
Regulatory Assets [Line Items]
Litigation Settlement, Amount			$ 53,000,000
Damages awarded for previously capitalized costs		41,000,000
Damages awarded for previously recorded operation and maintenance		2,000,000
Reduction of previously recorded deprecation expense		3,000,000
Plant balance reduction		38,000,000
Previously recorded nuclear fuel expense		10,000,000
System Energy [Member]
Regulatory Assets [Line Items]
Other Receivables		$ 1,217,000						$ 4,574,000		$ 1,217,000		$ 4,574,000
System Energy [Member] | Grand Gulf [Member]
Regulatory Assets [Line Items]
Litigation Settlement, Amount					$ 49,000,000
Damages awarded for previously capitalized costs			16,000,000
Damages awarded for previously recorded operation and maintenance			9,000,000
Reduction of previously recorded deprecation expense			4,000,000
Plant balance reduction			12,000,000
Previously recorded nuclear fuel expense			$ 19,000,000

Rate And Regulatory Matters (Na

Rate And Regulatory Matters (Narrative) (Details)	1 Months Ended																		3 Months Ended	9 Months Ended		36 Months Ended
	Oct. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Jul. 31, 2016USD ($)	Jun. 30, 2016USD ($)	May 31, 2016USD ($)	Apr. 30, 2016USD ($)	Mar. 31, 2016USD ($)	Feb. 29, 2016USD ($)	Jan. 31, 2016	Dec. 31, 2015USD ($)	Nov. 30, 2015USD ($)	Sep. 30, 2015USD ($)	Jul. 31, 2015USD ($)	Apr. 30, 2015USD ($)	Feb. 28, 2015USD ($)	Dec. 31, 2014USD ($)	Jul. 31, 2014USD ($)	Jan. 31, 2013USD ($)intervenor	Dec. 31, 2015USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Mar. 31, 2016USD ($)	May 31, 2015USD ($)	Jan. 31, 2015USD ($)
Commitments and Contingencies [Abstract]
Deferred Fuel Cost		$ 41,686,000								$ 0									$ 0	$ 41,686,000
Payments to Acquire Property, Plant, and Equipment																				(949,329,000)	$ 0
Impairment of Long-Lived Assets Held-for-use																				33,170,000	1,642,204,000
Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Refund to customers per LPSC Staff January 2013 audit report																		$ 1,900,000
Realignment of the recovery from Entergy Louisiana's fuel adjustment clause to base rates per LPSC January 2013 audit report																		$ 1,000,000
Number of Parties That Intervened in LPSC Proceeding | intervenor																		2
Number of Intervenors | intervenor																		1
Commitments and Contingencies [Abstract]
Public Utilities Earned Return On Common Equity					9.07%
LPSC staff recommended fuel refund including interest							$ 8,600,000
Refund To Customers																				43,000,000
One-time credit to customers resulting from potential future service credits		24,000,000																		24,000,000
Amount of LPSC Recommended Realignment of Fuel Costs to Base Rates							12,700,000
LPSC previously recommended disallowance of portion of refund to customers		3,400,000
Payments to Acquire Property, Plant, and Equipment							(474,000,000)													(474,670,000)	0
Earned return on common equity									10.22%
Estimated costs at completion for Ninemile 6 project													$ 648,000,000
Decrease in estimated costs at completion for Ninemile 6 project													76,000,000
Adjustment to formula rate plan to increase Legacy Entergy Louisiana additional capacity mechanism					$ 14,200,000
Adjustment to formula rate plan to increase Legacy Entergy Gulf States Louisiana additional capacity mechanism					500,000
Adjustment to formula rate plan to increase Legacy Entergy Louisiana revenues due to effect of system agreement termination					10,000,000
Adjustment to formula rate plan to decrease Legacy Entergy Gulf States Louisiana revenues due to effect of system agreement termination					58,700,000
Adjustment to formula rate plan for increase in MISO cost recovery mechanism					11,000,000
Recommended potential project and replacement power cost disallowances																	$ 71,000,000
Intervenor Recommended Disallowance of Incremental Project Costs																	$ 141,000,000
Impairment of Long-Lived Assets Held-for-use																$ 16,000,000
ALJ Recommended Disallowance of Capital Costs										67,000,000
Project and Replacement Power Cost Disallowances										2,000,000
ALJ Recommended Charges Related to Waterford 3 Steam Generator Project																			77,000,000
Write-Off of Waterford 3 Replacement Steam Generator																			45,000,000
Regulatory Charge Recorded Due to Probability of Non-Recovery Per ALJ Recommendation																			32,000,000
Entergy Mississippi [Member]
Commitments and Contingencies [Abstract]
Public Utilities Earned Return On Common Equity				10.07%
Deferred Fuel Over-Recovery Balance																							$ 58,300,000
Under-Recovery Under Power Management Rider																							$ 12,300,000
Net Over-Recovery of Rider Revenues													46,000,000
Projected Over-Recovery Energy Cost Recovery Rider								$ 68,000,000				$ 48,000,000									48,000,000
Public Utilities, Requested Rate Increase (Decrease), Amount							$ 32,600,000
Public Utilities, Requested Return on Equity, Percentage							9.96%
Public Utilities, Approved Rate Increase (Decrease), Amount				$ 23,700,000
Rate Increase Included in Formula Rate Plan				19,400,000
Storm Reserve Accrual Hurricane Isaac															$ 0
Increase in expenses to be collected through ad valorem tax adjustment rider				4,300,000
Authorized Storm Damage Reserve Balance		15,000,000																		15,000,000				$ 15,000,000
Balance At Which Storm Damage Accrual Will Return To Current Level															$ 10,000,000
Upper limit not exceeded for storm accrual balance						$ 10,000,000
Entergy Mississippi [Member] | Subsequent Event [Member]
Commitments and Contingencies [Abstract]
Storm Reserve Accrual Hurricane Isaac	$ 0
Balance At Which Storm Damage Accrual Will Return To Current Level	10,000,000
Entergy New Orleans [Member]
Commitments and Contingencies [Abstract]
Long-term payable due to Entergy Louisiana		20,527,000								20,527,000									20,527,000	20,527,000
Payments to Acquire Property, Plant, and Equipment							$ (237,000,000)													(237,335,000)	0
Monthly customer credits			$ 1,400,000
Authorized monthly customer credits											$ 400,000
Proposed annual customer credits			5,000,000
Redemption of Preferred Equity			21,000,000
Call Premium on Preferred Stock			819,000
Entergy New Orleans [Member] | Subsequent Event [Member]
Commitments and Contingencies [Abstract]
Estimated Net benefit to Customers Anticipated with AMI Deployment	101,000,000
Book Value of Existing Meters to be Retired with AMI Deployment	21,000,000
Entergy Texas [Member]
Commitments and Contingencies [Abstract]
Public Utilities, Requested Rate Increase (Decrease), Amount												13,000,000
Public Utilities, Approved Rate Increase (Decrease), Amount			10,500,000
Amount Collected From Customers		29,500,000
Authorized collection through TCRF rider		10,500,000
Refund To Customers				$ 68,000,000		56,200,000
Refund for fuel cost recovery						41,800,000
System Agreement Bandwidth Refund Related to Calendar Year 2006 Production Costs													$ 10,900,000
System Agreement Bandwidth Refund Related to Calendar Year 2006-2008 Production Costs						$ 3,500,000
Reduction in approved retail rate increase											2,000,000
Intervenor Recommended Disallowance Due to Load Growth Adjustment											$ 3,400,000
Jurisdictional eligible fuel and purchased power expenses, net of credits																						$ 1,770,000,000
Estimated deferred fuel over recovery balance for reconciliation period			19,300,000
Entergy Arkansas [Member]
Commitments and Contingencies [Abstract]
APSC and Intervener Recommended Revenue Requirement												$ 217,900,000
APSC and Intervener Recommended Return on Equity												9.65%
Rate Increase										225,000,000
Net increase in revenues										$ 133,000,000				$ 167,000,000
Authorized return on common equity										9.75%
Deferred Fuel Cost		41,686,000								$ 0									$ 0	41,686,000
Public Utilities, Requested Rate Increase (Decrease), Amount			$ 67,700,000											$ 268,400,000
Public Utilities, Requested Return on Equity, Percentage			9.75%											10.20%
Estimated Net benefit to Customers Anticipated with AMI Deployment		431,000,000
Book Value of Existing Meters to be Retired with AMI Deployment		$ 57,000,000																		57,000,000
Basis Point Band										5000.00%
Payments to Acquire Property, Plant, and Equipment							(237,000,000)													$ (237,324,000)	$ 0
Post-Fukushima Compliance Costs										$ 7,700,000
Flood Barrier Compliance Costs										$ 9,900,000
Reduction in approved retail rate increase								$ 5,000,000
Interim Base Rate Adjustment Surcharge Recovery							21,100,000
ALJ Recommended Percentage By Which Payments Be Reduced						20.00%
Liability Recorded Related to Estimated Payments Due Utility Operating Companies							87,000,000															87,000,000
Regulatory Asset Recorded to Represent Estimate of Recoverable Retail Portion of Costs							$ 75,000,000															$ 75,000,000
Redetermination Of Production Cost Allocation Rider Unrecovered Retail Balance					$ 1,900,000
Entergy Arkansas [Member] | Subsequent Event [Member]
Commitments and Contingencies [Abstract]
Public Utilities, Requested Increase in Revenue Requirement	$ 54,400,000

Equity (Narrative) (Details)

Equity (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	Oct. 28, 2016	Oct. 31, 2016	Sep. 30, 2016	May 31, 2016	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Equity [Abstract]
Stock Options Excluded From Diluted Common Shares Outstanding Calculation					3,500,000	7,400,000	4,600,000	7,400,000
Dividends, Common Stock, Cash							$ 455,993	$ 447,268
Shares, Issued			738,579		738,579		738,579
Common stock dividend (in dollars per share)					$ 0.85	$ 0.83	$ 2.55	$ 2.49
Entergy Louisiana [Member]
Equity [Abstract]
Dividends, Common Stock, Cash							$ 215,000	$ 100,000
Entergy Arkansas [Member] | Preferred Stock Cumulative One Hundred Dollar Par Value Six Point Zero Eight Percent Series [Member]
Equity [Abstract]
Redemption of Preferred Equity			$ 10,000
Preferred Stock, Dividend Rate, Percentage			6.08%
Entergy Arkansas [Member] | Preferred Stock Cumulative Twenty Five Dollar Par Value Six Point Four Five Percent Series [Member]
Equity [Abstract]
Redemption of Preferred Equity			$ 75,000
Preferred Stock, Dividend Rate, Percentage			6.45%
Entergy Mississippi [Member]
Equity [Abstract]
Dividends, Common Stock, Cash							24,000	36,250
System Energy [Member]
Equity [Abstract]
Dividends, Common Stock, Cash				$ 40,000			$ 139,000	$ 130,750
Subsequent Event [Member]
Equity [Abstract]
Common stock dividend (in dollars per share)	$ 0.87
Subsequent Event [Member] | Entergy Mississippi [Member] | Preferred Stock Cumulative Twenty Five Dollar Par Value Six Point Two Five Percent Series [Member]
Equity [Abstract]
Redemption of Preferred Equity		$ 30,000
Preferred Stock, Dividend Rate, Percentage		6.25%

Equity (Schedule Of Earnings Pe

Equity (Schedule Of Earnings Per Share, Basic And Diluted) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Basic earnings per share
Net income (loss) attributable to Entergy Corporation, Income	$ 388,170	$ (723,027)	$ 1,185,449	$ (276,135)
Net Income Attributable to Entergy Corporation, Shares	179,023,351	179,151,832	178,804,148	179,442,172
Net Income Attributable to Entergy Corporation, $/share	$ 2.17	$ (4.04)	$ 6.63	$ (1.54)
Average dilutive effect of:
Stock options, Shares	300,000	0	200,000	0
Stock options $/share	$ 0	$ 0	$ (0.01)	$ 0
Restricted stock, Shares	700,000	0	500,000	0
Restricted stock $/share	$ (0.01)	$ 0	$ (0.02)	$ 0
Diluted earnings per share, Shares	179,990,888	179,151,832	179,490,060	179,442,172
Diluted earnings per share $/share	$ 2.16	$ (4.04)	$ 6.60	$ (1.54)

Equity (Accumulated Other Compr

Equity (Accumulated Other Comprehensive Income (Loss))(Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	$ (9,155)	$ (46,816)	$ 8,951	$ (42,307)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	68,109	(19,609)	171,878	35,970
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(20,818)	(51,373)	(142,693)	(111,461)
Other comprehensive income (loss)	47,291	(70,982)	29,185	(75,491)
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	38,136	(117,798)	38,136	(117,798)
Foreign Currency Translation [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	840	2,785	2,028	2,669
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(92)	(469)	(1,280)	(353)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	0	0	0	0
Other comprehensive income (loss)	(92)	(469)	(1,280)	(353)
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	748	2,316	748	2,316
Net Unrealized Investment Gains [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	411,581	396,818	367,557	426,695
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	23,039	(50,760)	72,087	(63,210)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(1,672)	(3,206)	(6,696)	(20,633)
Other comprehensive income (loss)	21,367	(53,966)	65,391	(83,843)
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	432,948	342,852	432,948	342,852
Pension And Other Postretirement Liabilities [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	(453,999)	(553,903)	(466,604)	(569,789)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0	0	0	13
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	5,044	7,437	17,649	23,310
Other comprehensive income (loss)	5,044	7,437	17,649	23,323
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	(448,955)	(546,466)	(448,955)	(546,466)
Cash Flow Hedges Net Unrealized Gain [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	32,423	107,484	105,970	98,118
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	45,162	31,620	101,071	99,520
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(24,190)	(55,604)	(153,646)	(114,138)
Other comprehensive income (loss)	20,972	(23,984)	(52,575)	(14,618)
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	53,395	83,500	53,395	83,500
Entergy Louisiana [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance			(56,412)
Other comprehensive income (loss)	(232)	412	(725)	1,204
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	(57,137)		(57,137)
Entergy Louisiana [Member] | Pension And Other Postretirement Liabilities [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	(56,905)	(78,431)	(56,412)	(79,223)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(232)	412	(725)	1,204
Other comprehensive income (loss)	(232)	412	(725)	1,204
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	$ (57,137)	$ (78,019)	$ (57,137)	$ (78,019)

Equity (Reclassification out of

Equity (Reclassification out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016		Sep. 30, 2015
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Competitive Energy Revenue	$ 475,345	$ 521,746	$ 1,341,534		$ 1,603,643
Other Nonoperating Income (Expense)	(6,740)	(10,005)	(25,702)		(34,769)
INCOME (LOSS) BEFORE INCOME TAXES	651,110	(1,085,898)	1,349,914		(378,995)
Income taxes (benefits)	(257,906)	367,665	(148,879)		117,412
Consolidated net income (loss)	393,204	(718,233)	1,201,035	[1]	(261,583)	[1]
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Consolidated net income (loss)	20,818	51,373	142,693		111,461
Accumulated Net Unrealized Investment Gain (Loss) [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Consolidated net income (loss)	1,672	3,206	6,696		20,633
Parent Company [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Competitive Energy Revenue	37,550	86,020	237,483		177,129
Other Nonoperating Income (Expense)	(334)	(477)	(1,104)		(1,533)
INCOME (LOSS) BEFORE INCOME TAXES	37,216	85,543	236,379		175,596
Income taxes (benefits)	(13,026)	(29,939)	(82,733)		(61,458)
Consolidated net income (loss)	24,190	55,604	153,646		114,138
Parent Company [Member] | Accumulated Net Unrealized Investment Gain (Loss) [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Realized gain (loss)	3,279	6,286	13,129		40,457
Income taxes (benefits)	(1,607)	(3,080)	(6,433)		(19,824)
Parent Company [Member] | Accumulated Defined Benefit Plans Adjustment [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Settlements	(1,279)		(1,279)
Amortization of prior-service credit	7,354	5,985	22,064		17,956
Amortization of loss	(15,183)	(17,588)	(45,535)		(52,764)
INCOME (LOSS) BEFORE INCOME TAXES	(9,108)	(11,603)	(24,750)		(34,808)
Income taxes (benefits)	4,064	4,166	7,101		11,498
Consolidated net income (loss)	(5,044)	(7,437)	(17,649)		(23,310)
Entergy Louisiana [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Nonoperating Income (Expense)	(4,429)	(2,976)	(10,044)		(7,764)
INCOME (LOSS) BEFORE INCOME TAXES	289,047	273,208	618,630		604,965
Income taxes (benefits)	(99,541)	(86,068)	(64,193)		(182,735)
Consolidated net income (loss)	189,506	187,140	554,437		422,230
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior-service credit	1,947	1,866	5,841		5,599
Amortization of loss	(1,570)	(2,536)	(4,712)		(7,606)
INCOME (LOSS) BEFORE INCOME TAXES	377	(670)	1,129		(2,007)
Income taxes (benefits)	(145)	258	(404)		803
Consolidated net income (loss)	$ 232	$ (412)	$ 725		$ (1,204)
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $15.6 million and $9.6 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Revolving Credit Facilities, 37

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, 2016	Sep. 30, 2016	Aug. 31, 2016	Jul. 31, 2016	Jun. 30, 2016	May 31, 2016	Apr. 30, 2016	Mar. 31, 2016	Feb. 29, 2016	Jan. 31, 2016	Sep. 30, 2016
Debt Instrument [Line Items]
Amount of Facility		$ 3,500,000									$ 3,500,000
Issuance of letters of credit, percentage of total borrowing capacity		50.00%									50.00%
Line of credit facility, commitment fee percentage											0.225%
Amount Drawn/ Outstanding		$ 180,000									$ 180,000
Commercial Paper program limit		1,500,000									1,500,000
Commercial Paper Amount Outstanding		$ 264,000									$ 264,000
Commercial Paper Program [Member]
Debt Instrument [Line Items]
Debt, weighted average interest rate		1.14%									1.14%
Credit Facility [Member]
Debt Instrument [Line Items]
Debt, weighted average interest rate		2.24%									2.24%
Senior Secured Notes, Two Point Nine Five Percent Series Due September Two Thousand Twenty Six [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			2.95%
Issuance Of Debt			$ 750,000
Senior Secured Notes, Four Point Seven Percent Series Due January Two Thousand Seventeen [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			4.70%
Anticipated redemption of debt instrument			$ 500,000
Entergy Arkansas [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		$ 250,000									$ 250,000
Issuance of letters of credit, percentage of total borrowing capacity		50.00%									50.00%
Entergy Arkansas [Member] | Preferred Stock Cumulative One Hundred Dollar Par Value Six Point Zero Eight Percent Series [Member]
Debt Instrument [Line Items]
Redemption of Preferred Equity		$ 10,000
Preferred Stock, Dividend Rate, Percentage		6.08%
Entergy Arkansas [Member] | Preferred Stock Cumulative Twenty Five Dollar Par Value Six Point Four Five Percent Series [Member]
Debt Instrument [Line Items]
Redemption of Preferred Equity		$ 75,000
Preferred Stock, Dividend Rate, Percentage		6.45%
Entergy Arkansas [Member] | Mortgage Bonds Six Point Three Eight Percent Series Due November Twenty Thirty Four [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				6.38%
Redemption of debt instrument				$ 60,000
Entergy Arkansas [Member] | Mortgage Bonds Five Point Sixty Six Percent Series due February Two Thousand Twenty Five [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage									5.66%
Redemption of debt instrument									$ 175,000
Entergy Arkansas [Member] | Mortgage Bonds, Four Point Eight Seven Five Percent Series, Due September Two Thousand Sixty Six [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			4.875%
Issuance Of Debt			$ 410,000
Entergy Arkansas [Member] | Mortgage Bonds Five Point Seven Five Percent Series Due November Twenty Forty [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			5.75%
Redemption of debt instrument			$ 225,000
Entergy Arkansas [Member] | Mortgage Bonds Five Point Nine Percent Series Due June Two Thousand Thirty Three [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			5.90%
Redemption of debt instrument			$ 100,000
Entergy Arkansas [Member] | Three Point Five Percent Series First Mortgage Bonds Due April Two Thousand Twenty Six [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					3.50%					3.50%
Issuance Of Debt					$ 55,000					$ 325,000
Entergy Louisiana [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		$ 450,000									$ 450,000
Issuance of letters of credit, percentage of total borrowing capacity		50.00%									50.00%
Cash payment representing the purchase price to acquire the undivided interests in Waterford 3								$ 60,000
Entergy Louisiana [Member] | Mortgage Bonds, Four Point Ninety Five Percent Series, Due January Two Thousand Forty Five [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage								4.95%
Issuance Of Debt								$ 200,000
Entergy Louisiana [Member] | Mortgage Bonds, Three Point Two Five Percent Series, Due April Twenty Twenty Eight [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage								3.25%
Issuance Of Debt								$ 425,000
Entergy Louisiana [Member] | Mortgage Notes, Waterford 3 Series [Member]
Debt Instrument [Line Items]
Issuance Of Debt								$ 51,972
Entergy Louisiana [Member] | Mortgage Bonds Three Point Zero Five Percent Series Due June Two Thousand Thirty One [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage						3.05%
Issuance Of Debt						$ 325,000
Entergy Louisiana [Member] | Mortgage Bonds Six Point Two Percent Series Due July Two Thousand Thirty Three [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					6.20%
Redemption of debt instrument					$ 240,000
Entergy Louisiana [Member] | Mortgage Bonds Six Point One Eight Percent Series Due March Two Thousand Thirty Five [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					6.18%
Redemption of debt instrument					$ 85,000
Entergy Louisiana [Member] | Mortgage Bonds, Four Point Eight Seven Five Percent Series, Due September Two Thousand Sixty Six [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			4.875%
Issuance Of Debt			$ 270,000
Entergy Louisiana [Member] | Mortgage Bonds Six Point Zero Percent Series Due March Two Thousand Forty [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		6.00%									6.00%
Redemption of debt instrument		$ 118,000
Entergy Louisiana [Member] | Mortgage Bonds Five Point Eight Seven Five Percent Series Due June Two Thousand Forty One [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		5.875%									5.875%
Redemption of debt instrument		$ 150,000
Entergy Louisiana [Member] | Governmental Bonds, Three Point Three Seven Five Percent, Due September Twenty Twenty Eight [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage								3.375%
Issuance Of Debt								$ 83,680
Entergy Louisiana [Member] | Governmental Bonds, Three Point Five Zero Percent, Due June Twenty Thirty [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage								3.50%
Issuance Of Debt								$ 115,000
Entergy Louisiana [Member] | Pollution Control Revenue Bonds [Member]
Debt Instrument [Line Items]
Redemption of debt instrument							$ 198,680
Entergy Mississippi [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		$ 175,000									$ 175,000
Entergy Mississippi [Member] | Mortgage Bonds Two Point Eight Five Percent Series Due June Two Thousand Twenty Eight [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage						2.85%
Issuance Of Debt						$ 375,000
Entergy Mississippi [Member] | Mortgage Bonds Three Point Two Five Percent Series Due June Two Thousand Sixteen [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					3.25%
Redemption of debt instrument					$ 125,000
Entergy Mississippi [Member] | Mortgage Bonds Six Point Zero Percent Series Due November Two Thousand Thirty Two [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					6.00%
Redemption of debt instrument					$ 75,000
Entergy Mississippi [Member] | Mortgage Bonds Six Point Two Five Percent Series Due April Two Thousand Thirty Four [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					6.25%
Redemption of debt instrument					$ 100,000
Entergy Mississippi [Member] | Mortgage Bonds, Four Point Nine Zero Percent Series, Due October Two Thousand Sixty Six [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		4.90%									4.90%
Issuance Of Debt		$ 260,000
Entergy Mississippi [Member] | Governmental Bonds Four Point Nine Zero Percent Series Due Two Thousand Twenty Two Independence County [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					4.90%
Redemption of debt instrument					$ 30,000
Entergy Texas [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		$ 200,000									$ 200,000
Issuance of letters of credit, percentage of total borrowing capacity		50.00%									50.00%
Entergy Texas [Member] | Mortgage Bonds, Two Point Five Five Series, Due June Twenty Twenty One [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage								2.55%
Issuance Of Debt								$ 125,000
System Energy [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		$ 200,000									$ 200,000
System Energy [Member] | Five Point Eight Seven Five Percent Governmental Bonds Due 2022 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage						5.875%
Redemption of debt instrument						$ 22,000
Long-term Debt, Gross						$ 156,000
Entergy Nuclear Vermont Yankee [Member]
Debt Instrument [Line Items]
Amount of Facility								$ 100,000
Line of credit facility, commitment fee percentage											0.20%
Amount Drawn/ Outstanding		41,500									$ 41,500
Line of Credit Facility, Interest Rate During Period											2.19%
Uncommitted Credit Facility		85,000									$ 85,000
Uncommitted Line of Credit Facility Interest Rate During Period											2.27%
Entergy New Orleans [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		100,000									$ 100,000
Issuance of letters of credit, limit of total borrowing capacity		10,000									10,000
Redemption of Preferred Equity				$ 21,000
Entergy New Orleans [Member] | Mortgage Bonds, Five Point Five Zero Percent Series, Due April Twenty Sixty Six [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage								5.50%
Issuance Of Debt								$ 110,000
Entergy New Orleans [Member] | Mortgage Bonds Four Percent Series Due June Two Thousand Twenty Six [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage						4.00%
Issuance Of Debt						$ 85,000
Entergy New Orleans [Member] | Mortgage Bonds Five Point Six Percent Series Due September Two Thousand Twenty Four [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					5.60%
Redemption of debt instrument					$ 33,271
Entergy New Orleans [Member] | Mortgage Bonds Five Point Six Five Percent Series Due September Two Thousand Twenty Nine [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					5.65%
Redemption of debt instrument					$ 37,772
System Energy VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		$ 80,000									$ 80,000
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%
Entergy Arkansas VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		$ 47,400									$ 47,400
Line of credit facility commitment fee as a percentage of undrawn commitment amount											0.10%
Entergy Arkansas VIE [Member] | Variable Interest Entity Notes Payable Three Point Two Three Percent Series J Due July Two Thousand Sixteen [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				3.23%
Redemption of debt instrument				$ 55,000
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 VIE [Member]
Debt Instrument [Line Items]
Line of credit facility commitment fee as a percentage of undrawn commitment amount											0.10%
Entergy Louisiana VIE [Member] | Variable Interest Entity Notes Payable Three Point Three Zero Percent Series F Due March Two Thousand Sixteen [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage								3.30%
Redemption of debt instrument								$ 20,000
Entergy Louisiana Waterford VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		$ 42,000									$ 42,000
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		$ 0									$ 0
Maximum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment fee percentage											0.275%
Consolidated debt ratio		65.00%									65.00%
Maximum [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		65.00%									65.00%
Maximum [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		65.00%									65.00%
Maximum [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		65.00%									65.00%
Maximum [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		65.00%									65.00%
Maximum [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		65.00%									65.00%
Maximum [Member] | System Energy VIE [Member]
Debt Instrument [Line Items]
Consolidated debt ratio of total capitalization											70.00%
Maximum [Member] | Entergy Arkansas VIE [Member]
Debt Instrument [Line Items]
Consolidated debt ratio of total capitalization											70.00%
Maximum [Member] | Entergy Louisiana VIE [Member]
Debt Instrument [Line Items]
Consolidated debt ratio of total capitalization											70.00%
Minimum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment fee percentage											0.075%
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Amount of Facility		$ 150,000									$ 150,000
Letters of Credit Outstanding, Amount		0									0
Amount Drawn/ Outstanding		0									$ 0
Line of Credit Facility, Interest Rate During Period											1.77%
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		4,700									4,700
Amount Drawn/ Outstanding		$ 0									$ 0
Line of Credit Facility, Interest Rate During Period											2.02%
Subsequent Event [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Repayment of Waterford 3 lessor debt due January 2017	$ 57,000
Subsequent Event [Member] | Entergy Louisiana [Member] | Mortgage Bonds Two Point Four Percent Series Due October Two Thousand Twenty Six [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	2.40%
Issuance Of Debt	$ 400,000
Subsequent Event [Member] | Entergy Mississippi [Member] | Preferred Stock Cumulative Twenty Five Dollar Par Value Six Point Two Five Percent Series [Member]
Debt Instrument [Line Items]
Redemption of Preferred Equity	$ 30,000
Preferred Stock, Dividend Rate, Percentage	6.25%
Subsequent Event [Member] | Entergy Mississippi [Member] | Mortgage Bonds Six Point Two Percent Series Due April Two Thousand Forty [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	6.20%
Redemption of debt instrument	$ 80,000
Subsequent Event [Member] | Entergy Mississippi [Member] | Mortgage Bonds Six Point Zero Percent Series Due May Two Thousand Fifty One [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	6.00%
Redemption of debt instrument	$ 150,000

Revolving Credit Facilities, 38

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, 2016USD ($)
Summary of the borrowings outstanding and capacity available under the facility
Capacity	$ 3,500
Amount Drawn/ Outstanding	180
Letters of Credit	6
Capacity Available	$ 3,314

Revolving Credit Facilities, 39

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Credit Facilities) (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2016USD ($)
Amount of Facility	$ 3,500,000
Amount Drawn/ Outstanding	$ 180,000
Entergy Arkansas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Aug. 14, 2021
Amount of Facility	$ 150,000
Interest Rate	1.77%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Arkansas [Member] | Credit Facility Of Twenty Million [Member]
Expiration Date	Apr. 30, 2017
Amount of Facility	$ 20,000
Interest Rate	1.77%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Louisiana [Member] | Credit Facility Of Three Hundred Fifty Million [Member]
Expiration Date	Aug. 14, 2021
Amount of Facility	$ 350,000
Interest Rate	1.77%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 6,400
Entergy Mississippi [Member] | Credit Facility Of Thirty Seven Point Five Million [Member]
Expiration Date	May 31, 2017
Amount of Facility	$ 37,500
Interest Rate	2.02%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Thirty Five Million [Member]
Expiration Date	May 31, 2017
Amount of Facility	$ 35,000
Interest Rate	2.02%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Twenty Million [Member]
Expiration Date	May 31, 2017
Amount of Facility	$ 20,000
Interest Rate	2.02%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Ten Million [Member]
Expiration Date	May 31, 2017
Amount of Facility	$ 10,000
Interest Rate	2.02%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy New Orleans [Member] | Credit Facility Of Twenty Five Million [Member]
Expiration Date	Nov. 20, 2018
Amount of Facility	$ 25,000
Interest Rate	2.27%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 800
Entergy Texas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Aug. 14, 2021
Amount of Facility	$ 150,000
Interest Rate	2.02%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 4,700

Revolving Credit Facilities, 40

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, 2016USD ($)
Entergy Arkansas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	$ 250
Borrowings	49
Entergy Louisiana [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	450
Borrowings	0
Entergy Mississippi [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	175
Borrowings	0
Entergy New Orleans [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	100
Borrowings	0
Entergy Texas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	12
System Energy [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	$ 0

Revolving Credit Facilities, 41

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, 2016USD ($)
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount Drawn/ Outstanding	$ 180
Entergy Arkansas VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	May 16, 2019
Amount of Facility	$ 80
Weighted Average Interest Rate on Borrowings	2.15%
Amount Drawn/ Outstanding	$ 47.4
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	May 16, 2019
Amount of Facility	$ 120
Weighted Average Interest Rate on Borrowings	2.13%
Amount Drawn/ Outstanding	$ 80
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	May 16, 2019
Amount of Facility	$ 105
Amount Drawn/ Outstanding	$ 0
Entergy Louisiana Waterford VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	May 16, 2019
Amount of Facility	$ 85
Weighted Average Interest Rate on Borrowings	2.14%
Amount Drawn/ Outstanding	$ 42

Revolving Credit Facilities, 42

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Notes Payable By Variable Interest Entities) (Details) $ in Millions	Sep. 30, 2016USD ($)
Two Point Six Two Percent Series K Notes Due December Two Thousand Seventeen [Member] | Entergy Arkansas VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	2.62%
Amount	$ 60
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 Two Five Percent Series Q Due July Two Thousand Seventeen [Member] | Entergy Louisiana River Bend VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.25%
Amount	$ 75
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 Two Five Percent Series G Due July Two Thousand Seventeen [Member] | Entergy Louisiana Waterford VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.25%
Amount	$ 25
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
Four Point Zero Two Percent Series H Notes Due February Two Thousand Seventeen [Member] | System Energy VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	4.02%
Amount	$ 50
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

Revolving Credit Facilities, 43

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, 2016	Dec. 31, 2015
Short-term Debt [Line Items]
Long-term Debt, Fair Value	$ 15,424,412	$ 13,578,511
Long-term Debt, Book Value	14,611,903	13,325,930
Notes payable to power authority		35,000
Entergy Arkansas [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	2,791,291	2,498,108
Long-term Debt, Book Value	2,796,059	2,629,839
Long term DOE obligations	182,000	181,000
Entergy Louisiana [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	5,848,345	5,018,786
Long-term Debt, Book Value	5,407,897	4,836,162
Capital Lease Obligations	57,000	109,000
Entergy Mississippi [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	1,409,719	1,087,326
Long-term Debt, Book Value	1,344,305	1,045,085
Entergy New Orleans [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	502,194	351,040
Long-term Debt, Book Value	459,295	342,880
Entergy Texas [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	1,683,655	1,590,616
Long-term Debt, Book Value	1,521,270	1,451,967
System Energy [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	543,933	552,762
Long-term Debt, Book Value	551,023	572,667
Capital Lease Obligations	$ 34,000	$ 34,000

Revolving Credit Facilities, 44

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) $ in Millions	Sep. 30, 2016USD ($)
Credit Facility Of Twenty Five Million [Member] | Entergy Arkansas [Member]
Uncommitted Credit Facility	$ 25
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 1
Credit Facility of Fifty Million [Member] | Entergy Texas [Member]
Uncommitted Credit Facility	$ 50
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 16
Credit Facility of Forty Million [Member] | Entergy Mississippi [Member]
Uncommitted Credit Facility	$ 40
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 10.2
Credit Facility of Fifteen Million [Member] | Entergy New Orleans [Member]
Uncommitted Credit Facility	$ 15
Letter of Credit Fee, Percentage	0.75%
Letters of Credit Outstanding, Amount	$ 12.9
Credit Facility Of One Hundred Twenty Five Million [Member] | Entergy Louisiana [Member]
Uncommitted Credit Facility	$ 125
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 16.4

Stock Based Compensation (Narra

Stock Based Compensation (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	Jan. 28, 2016	Jan. 31, 2016	Mar. 31, 2016	Sep. 30, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option granted (in shares)			696,900
Weighted-average grant-date fair value of options granted (in dollars per share)			$ 7.40
Stock options outstanding				7,152,077
Weighted-average exercise price of stock options outstanding (in dollars per share)				$ 84.93
Intrinsic value in the money stock options				$ 17.7
Vesting period of awards under Entergy's plans, years				3 years
Equity Ownership And Long Term Cash Incentive Plan Two Thousand Eleven [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Long-term incentive plan awards		199,800
LTIP awards granted value (in dollars per share)	$ 84.52
Restricted Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock awards granted		370,000
Restricted stock awards granted value (in dollars per share)	$ 70.56

Stock-Based Compensation (Finan

Stock-Based Compensation (Financial Information For Stock Options) (Details) - Parent Company [Member] - Employee Stock Option [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 1.1	$ 1.1	$ 3.3	$ 3.2
Tax benefit recognized in Entergy's net income	0.5	0.4	1.3	1.2
Compensation cost capitalized as part of fixed assets and inventory	$ 0.2	$ 0.1	$ 0.6	$ 0.5

Stock-Based Compensation (Fin47

Stock-Based Compensation (Financial Information For Other Equity Plans) (Details) - Parent Company [Member] - Restricted Stock Awards [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 8.5	$ 8.6	$ 25.4	$ 24.7
Tax benefit recognized in Entergy's net income	3.3	3.3	9.8	9.5
Compensation cost capitalized as part of fixed assets and inventory	$ 2	$ 1.8	$ 5.7	$ 4.9

Retirement And Other Postreti48

Retirement And Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2016
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Expected current year pension contributions			$ 307,600
Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Pension contributions made through Year To Date					$ 390,100
Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Expected current year pension contributions			65,882
Remaining estimated pension contributions to be made in current year	$ 17,119		17,119
Entergy Arkansas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Pension contributions made through Year To Date					83,001
Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Expected current year pension contributions			12,649
Remaining estimated pension contributions to be made in current year	3,271		3,271
Entergy Texas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Pension contributions made through Year To Date					$ 15,920
Non-Qualified Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits			3,700
Non-Qualified Pension Plans [Member] | Parent Company [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	8,000	$ 4,500	16,500	$ 13,400
Non-Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	105	113	317	339
Non-Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	$ 126	$ 149	$ 380	$ 447

Retirement And Other Postreti49

Retirement And Other Postretirement Benefits (Components Of Qualified Net Pension Cost) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	$ 35,811	$ 43,762	$ 107,433	$ 131,286
Interest cost on projected benefit obligation	65,403	75,694	196,209	227,082
Expected return on assets	(97,366)	(98,655)	(292,098)	(295,965)
Amortization of prior service cost (credit)	270	390	810	1,170
Amortization of loss	48,824	58,981	146,472	176,943
Defined Benefit Plan, Special Termination Benefits			0	76
Net other postretirement benefit cost	52,942	80,172	158,826	240,592
Pension Plans Defined Benefit [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	5,181	6,661	15,543	19,983
Interest cost on projected benefit obligation	13,055	15,471	39,165	46,413
Expected return on assets	(19,772)	(20,026)	(59,316)	(60,078)
Amortization of loss	10,936	13,564	32,808	40,692
Net other postretirement benefit cost	9,400	15,670	28,200	47,010
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	7,049	8,599	21,147	25,797
Interest cost on projected benefit obligation	14,870	17,367	44,610	52,101
Expected return on assets	(22,096)	(22,701)	(66,288)	(68,103)
Amortization of loss	11,946	14,951	35,838	44,853
Net other postretirement benefit cost	11,769	18,216	35,307	54,648
Pension Plans Defined Benefit [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,562	1,982	4,686	5,946
Interest cost on projected benefit obligation	3,811	4,502	11,433	13,506
Expected return on assets	(5,981)	(6,105)	(17,943)	(18,315)
Amortization of loss	2,985	3,724	8,955	11,172
Net other postretirement benefit cost	2,377	4,103	7,131	12,309
Pension Plans Defined Benefit [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	656	849	1,968	2,547
Interest cost on projected benefit obligation	1,814	2,108	5,442	6,324
Expected return on assets	(2,687)	(2,725)	(8,061)	(8,175)
Amortization of loss	1,615	2,013	4,845	6,039
Net other postretirement benefit cost	1,398	2,245	4,194	6,735
Pension Plans Defined Benefit [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,416	1,645	4,248	4,935
Interest cost on projected benefit obligation	3,557	4,354	10,671	13,062
Expected return on assets	(6,062)	(6,222)	(18,186)	(18,666)
Amortization of loss	2,340	3,238	7,020	9,714
Net other postretirement benefit cost	1,251	3,015	3,753	9,045
Pension Plans Defined Benefit [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,566	1,957	4,698	5,871
Interest cost on projected benefit obligation	2,992	3,493	8,976	10,479
Expected return on assets	(4,459)	(4,568)	(13,377)	(13,704)
Amortization of loss	2,604	3,264	7,812	9,792
Net other postretirement benefit cost	2,703	4,146	8,109	12,438
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	8,073	11,326	24,219	33,978
Interest cost on projected benefit obligation	14,083	17,984	42,249	53,952
Expected return on assets	(10,455)	(11,344)	(31,365)	(34,032)
Amortization of prior service cost (credit)	(11,373)	(9,320)	(34,119)	(27,960)
Amortization of loss	4,554	7,893	13,662	23,679
Net other postretirement benefit cost	4,882	16,539	14,646	49,617
Other Postretirement [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	978	1,739	2,934	5,217
Interest cost on projected benefit obligation	2,324	3,130	6,972	9,390
Expected return on assets	(4,464)	(4,798)	(13,392)	(14,394)
Amortization of prior service cost (credit)	(1,368)	(610)	(4,104)	(1,830)
Amortization of loss	1,064	1,339	3,192	4,017
Net other postretirement benefit cost	(1,466)	800	(4,398)	2,400
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,869	2,474	5,607	7,422
Interest cost on projected benefit obligation	3,260	4,078	9,780	12,234
Expected return on assets	0	0	0	0
Amortization of prior service cost (credit)	(1,947)	(1,867)	(5,841)	(5,601)
Amortization of loss	732	1,780	2,196	5,340
Net other postretirement benefit cost	3,914	6,465	11,742	19,395
Other Postretirement [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	386	507	1,158	1,521
Interest cost on projected benefit obligation	709	859	2,127	2,577
Expected return on assets	(1,379)	(1,542)	(4,137)	(4,626)
Amortization of prior service cost (credit)	(234)	(229)	(702)	(687)
Amortization of loss	223	215	669	645
Net other postretirement benefit cost	(295)	(190)	(885)	(570)
Other Postretirement [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	156	205	468	615
Interest cost on projected benefit obligation	448	652	1,344	1,956
Expected return on assets	(1,154)	(1,201)	(3,462)	(3,603)
Amortization of prior service cost (credit)	(186)	(177)	(558)	(531)
Amortization of loss	37	118	111	354
Net other postretirement benefit cost	(699)	(403)	(2,097)	(1,209)
Other Postretirement [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	398	500	1,194	1,500
Interest cost on projected benefit obligation	1,039	1,342	3,117	4,026
Expected return on assets	(2,394)	(2,588)	(7,182)	(7,764)
Amortization of prior service cost (credit)	(681)	(681)	(2,043)	(2,043)
Amortization of loss	537	685	1,611	2,055
Net other postretirement benefit cost	(1,101)	(742)	(3,303)	(2,226)
Other Postretirement [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	334	470	1,002	1,410
Interest cost on projected benefit obligation	529	628	1,587	1,884
Expected return on assets	(814)	(911)	(2,442)	(2,733)
Amortization of prior service cost (credit)	(393)	(366)	(1,179)	(1,098)
Amortization of loss	287	300	861	900
Net other postretirement benefit cost	(57)	121	(171)	363
Non-Qualified Pension Plans [Member] | Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	8,000	4,500	16,500	13,400
Non-Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	105	113	317	339
Non-Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	58	68	176	204
Non-Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	60	59	179	177
Non-Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	16	16	48	48
Non-Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	$ 126	$ 149	$ 380	$ 447

Retirement And Other Postreti50

Retirement And Other Postretirement Benefits (Expected Employer Contributions) (Details) - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2016
Change in Plan Assets
Expected current year pension contributions	$ 307,600
Subsequent Event [Member]
Change in Plan Assets
Pension contributions made through Year To Date		$ 390,100
Entergy Arkansas [Member]
Change in Plan Assets
Expected current year pension contributions	65,882
Remaining estimated pension contributions to be made in current year	17,119
Entergy Arkansas [Member] | Subsequent Event [Member]
Change in Plan Assets
Pension contributions made through Year To Date		83,001
Entergy Louisiana [Member]
Change in Plan Assets
Expected current year pension contributions	67,116
Remaining estimated pension contributions to be made in current year	17,306
Entergy Louisiana [Member] | Subsequent Event [Member]
Change in Plan Assets
Pension contributions made through Year To Date		84,422
Entergy Mississippi [Member]
Change in Plan Assets
Expected current year pension contributions	15,981
Remaining estimated pension contributions to be made in current year	3,987
Entergy Mississippi [Member] | Subsequent Event [Member]
Change in Plan Assets
Pension contributions made through Year To Date		19,968
Entergy New Orleans [Member]
Change in Plan Assets
Expected current year pension contributions	8,456
Remaining estimated pension contributions to be made in current year	2,253
Entergy New Orleans [Member] | Subsequent Event [Member]
Change in Plan Assets
Pension contributions made through Year To Date		10,709
Entergy Texas [Member]
Change in Plan Assets
Expected current year pension contributions	12,649
Remaining estimated pension contributions to be made in current year	3,271
Entergy Texas [Member] | Subsequent Event [Member]
Change in Plan Assets
Pension contributions made through Year To Date		15,920
System Energy [Member]
Change in Plan Assets
Expected current year pension contributions	16,120
Remaining estimated pension contributions to be made in current year	$ 4,378
System Energy [Member] | Subsequent Event [Member]
Change in Plan Assets
Pension contributions made through Year To Date		$ 20,498

Retirement And Other Postreti51

Retirement And Other Postretirement Benefits (Reclassification Out Of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Defined Benefit Plan Disclosure [Line Items]
Total
Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	$ 7,354	5,985	$ 22,064	$ 17,956
Amortization of loss	(15,183)	(17,588)	(45,535)	(52,764)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(1,279)		(1,279)
Total	(9,108)	(11,603)	(24,750)	(34,808)
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,947	1,866	5,841	5,599
Amortization of loss	(1,570)	(2,536)	(4,712)	(7,606)
Total	377	(670)	1,129	(2,007)
Pension Plans Defined Benefit [Member] | Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(270)	(389)	(810)	(1,167)
Amortization of loss	(12,482)	(12,627)	(37,446)	(37,881)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0		0
Total	(12,752)	(13,016)	(38,256)	(39,048)
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	(836)	(751)	(2,508)	(2,253)
Total	(836)	(751)	(2,508)	(2,253)
Other Postretirement [Member] | Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	7,738	6,482	23,214	19,446
Amortization of loss	(2,063)	(4,409)	(6,189)	(13,227)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0		0
Total	5,675	2,073	17,025	6,219
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,947	1,867	5,841	5,601
Amortization of loss	(732)	(1,780)	(2,196)	(5,338)
Total	1,215	87	3,645	263
Non-Qualified Pension Plans [Member] | Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(114)	(108)	(340)	(323)
Amortization of loss	(638)	(552)	(1,900)	(1,656)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(1,279)		(1,279)
Total	(2,031)	(660)	(3,519)	(1,979)
Non-Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	(1)	0	(2)
Amortization of loss	(2)	(5)	(8)	(15)
Total	$ (2)	$ (6)	$ (8)	$ (17)

Business Segment Information (S

Business Segment Information (Segment Financial Information) (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016		Sep. 30, 2015		Dec. 31, 2015
Segment Financial Information
Operating revenues	$ 3,124,703,000	$ 3,371,406,000	$ 8,197,118,000		$ 9,004,728,000
Income taxes (benefits)	257,906,000	(367,665,000)	148,879,000		(117,412,000)
Consolidated net income (loss)	393,204,000	(718,233,000)	1,201,035,000	[1]	(261,583,000)	[1]
Assets	47,738,181,000		47,738,181,000				$ 44,647,681,000
Utility [Member]
Segment Financial Information
Operating revenues	2,649,392,000	2,849,681,000	6,855,664,000		7,401,136,000
Income taxes (benefits)	255,603,000	198,945,000	359,653,000		407,993,000
Consolidated net income (loss)	447,782,000	364,265,000	1,027,751,000		796,051,000
Assets	40,542,593,000		40,542,593,000				38,356,906,000
Entergy Wholesale Commodities [Member]
Segment Financial Information
Operating revenues	475,345,000	521,746,000	1,341,534,000		1,603,643,000
Income taxes (benefits)	6,115,000	(554,513,000)	(176,626,000)		(487,622,000)
Consolidated net income (loss)	8,221,000	(1,031,410,000)	338,651,000		(911,524,000)
Assets	9,100,779,000		9,100,779,000				8,210,183,000
All Other [Member]
Segment Financial Information
Operating revenues	0	0	0		0
Income taxes (benefits)	(3,812,000)	(12,097,000)	(34,148,000)		(37,783,000)
Consolidated net income (loss)	(30,901,000)	(19,190,000)	(69,672,000)		(50,415,000)
Assets	1,339,879,000		1,339,879,000				(461,505,000)
Eliminations [Member]
Segment Financial Information
Operating revenues	(34,000)	(21,000)	(80,000)		(51,000)
Income taxes (benefits)	0	0	0		0
Consolidated net income (loss)	(31,898,000)	$ (31,898,000)	(95,695,000)		$ (95,695,000)
Assets	$ (3,245,070,000)		$ (3,245,070,000)				$ (1,457,903,000)
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $15.6 million and $9.6 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Risk Management and Fair Valu53

Risk Management and Fair Values (Narrative) (Details) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2016USD ($)MMBTUMWh	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)MMBTUMWhcounterparty	Sep. 30, 2015USD ($)	Dec. 31, 2015USD ($)counterparty
Risk Management and Fair Values [Abstract]
Letters of Credit Held	$ 49		$ 49
Cash collateral posted	4		4		$ 9
Derivative, Collateral, Obligation to Return Cash	4		4		$ 68
Cash flow hedges relating to power sales as part of net unrealized gains			85
Reclassified from accumulated other comprehensive income (OCI) to operating revenues			$ 66
Number of Derivative Contract Counterparties in a Liability Position | counterparty			0		2
Maturity of cash flow hedges, Tax	$ 13	$ 30	$ 83	$ 61
Maximum length of time over which Company is currently hedging the variability in future cash flows for forecasted power transactions, years			2 years 3 months
Planned generation sold forward from non utility nuclear power plants for the remainder of the period			90.00%
Planned Generation Sold Forward under financial derivatives	61.00%		61.00%
Total planned generation for remainder of the period | MWh			9,000,000
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	25,604,000		25,604,000
Total volume of fixed transmission rights outstanding | MWh	74,491,000		74,491,000
Change in cash flow hedges due to ineffectiveness	$ 6.4	(0.9)	$ 6.1	0
Dollar amount of hedge contract in a liability position					$ 2
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset and Liability Unrealized Gains (Loss) Included in Earnings	$ 1	$ 12	$ 1	$ 5
Entergy Arkansas [Member]
Risk Management and Fair Values [Abstract]
Total volume of fixed transmission rights outstanding | MWh	16,859,000		16,859,000
Entergy Louisiana [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	18,780,000		18,780,000
Total volume of fixed transmission rights outstanding | MWh	31,476,000		31,476,000
Entergy Mississippi [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	5,750,000		5,750,000
Total volume of fixed transmission rights outstanding | MWh	12,374,000		12,374,000
Entergy New Orleans [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	1,074,000		1,074,000
Total volume of fixed transmission rights outstanding | MWh	3,640,000		3,640,000
Entergy Texas [Member]
Risk Management and Fair Values [Abstract]
Total volume of fixed transmission rights outstanding | MWh	9,745,000		9,745,000

Risk Management and Fair Valu54

Risk Management and Fair Values (Fair Values Of Derivative Instruments) (Details) - USD ($) $ in Millions		Sep. 30, 2016		Dec. 31, 2015
Assets:
Derivative asset as hedging instrument offset		$ (4)		$ (68)
Other Non-Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Liabilities:
Derivative liability as hedging instrument offset	[1]	(2)		(2)
Derivative Liability, Fair Value, Gross Liability	[2]	2		2
Derivative Liability	[3],[4]	0		0
Other Non-Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative liability as hedging instrument offset	[1]	(3)
Derivative Liability, Fair Value, Gross Liability	[2]	3
Derivative Liability	[3],[4]	0
Other Deferred Debits And Other Assets [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset	[2]	20		17
Derivative asset as hedging instrument offset	[1]	(5)		(2)
Derivative Asset	[3],[4]	15		15
Other Deferred Debits And Other Assets [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset	[2]	6
Derivative asset as hedging instrument offset	[1]	(1)
Derivative Asset	[3],[4]	5
Prepayments And Other [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset	[2]	67		173
Derivative asset as hedging instrument offset	[1]	(17)		(34)
Derivative Asset	[3],[4]	50		139
Prepayments And Other [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset	[2]	42		54
Derivative asset as hedging instrument offset	[1]	(17)		(13)
Derivative Asset	[3],[4]	25		41
Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Utility and Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset	[2]	32		24
Derivative asset as hedging instrument offset	[1]	(1)		(1)
Derivative Asset	[3],[4]	31		23
Other Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Liabilities:
Derivative liability as hedging instrument offset	[1]	(1)		(14)
Derivative Liability, Fair Value, Gross Liability	[2]	1		14
Derivative Liability	[3],[4]	0		0
Other Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative liability as hedging instrument offset	[1]	(34)		(32)
Derivative Liability, Fair Value, Gross Liability	[2]	34		38
Derivative Liability	[3],[4]	0		6
Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative liability as hedging instrument offset		0	[2]	0	[1]
Derivative Liability, Fair Value, Gross Liability	[2]	1		9
Derivative Liability	[3],[4]	1		9
Entergy Louisiana [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset		12.4		8.5
Entergy Louisiana [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability		0.4		7
Entergy Mississippi [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset		4		2.4
Entergy Mississippi [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability		0.1		1.3
Entergy New Orleans [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset		1.6		1.5
Entergy New Orleans [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability				0.5
Entergy Arkansas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset		8.1		7.9
Entergy Texas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset		$ 5.1		$ 2.2
[1]	Represents the netting of fair value balances with the same counterparty
[2]	Represents the gross amounts of recognized assets/liabilities
[3]	Excludes cash collateral in the amount of $4 million posted and $4 million held as of September 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $49 million held as of September 30, 2016.
[4]	Represents the net amounts of assets /liabilities presented on the Entergy Consolidated Balance Sheets

Risk Management and Fair Valu55

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, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Effect of Derivative instruments designated as cash flow hedges on consolidated statements of income
Amount of gain (loss) recognized in AOCI (effective portion)	$ 70	$ 49	$ 156	$ 154
Amount of gain reclassified from accumulated OCI into income (effective portion)	$ 37	$ 86	$ 237	$ 177

Risk Management and Fair Valu56

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, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
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	$ (9)	$ 0	$ 6	$ 1
Amount of gain (loss) recorded in income	0	(3)	(9)	(42)
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	25	(13)	(5)	(29)
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	37	51	96	130
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	7.1	13.9	20.3	48.6
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	19.5	(10.2)	(4.6)	(23.7)
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	20.4	17.9	52.5	49.7
Entergy Mississippi [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	5.3	(1.9)	0.3	(4.3)
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	6.7	6.7	11.1	13.9
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		(0.4)	(0.5)	(0.9)
Entergy New Orleans [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	0.9	1.5	2.8	7.5
Entergy Texas [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	$ 1.8	$ 10.9	$ 8.7	$ 10.7

Risk Management and Fair Valu57

Risk Management and Fair Values (Assets And Liabilities At Fair Value On A Recurring Basis) (Details) - USD ($) $ in Millions		Sep. 30, 2016	Dec. 31, 2015
Assets at fair value on a recurring basis
Assets other than temporary cash investments		$ 5,671	$ 5,350
Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		1,206	1,287
Liabilities at fair value on a recurring basis
Total			15
Assets, Fair Value Disclosure		7,490	7,330
Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		1	9
Power Contracts Liabilities [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			6
Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	451	468
Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	2,291	2,155
Common trust funds valued using Net Asset Value [Domain] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1],[2]	2,929	2,727
Power Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		95	195
Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		433	425
Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		54	50
Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		31	23
Fair Value Inputs Level 1 [Member]
Assets at fair value on a recurring basis
Temporary cash investments		1,206	1,287
Liabilities at fair value on a recurring basis
Total			9
Assets, Fair Value Disclosure		3,160	3,291
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	9
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] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	451	468
Fair Value Inputs Level 1 [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	1,016	1,061
Fair Value Inputs Level 1 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value Inputs Level 1 [Member] | Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		433	425
Fair Value Inputs Level 1 [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		54	50
Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 2 [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Total			0
Assets, Fair Value Disclosure		1,275	1,094
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
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] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	0	0
Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	1,275	1,094
Fair Value, Inputs, Level 2 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 2 [Member] | Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 2 [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 3 [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Total			6
Assets, Fair Value Disclosure		126	218
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Fair Value, Inputs, Level 3 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			6
Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 3 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		95	195
Fair Value, Inputs, Level 3 [Member] | Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 3 [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		31	23
Entergy Louisiana [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		1,124.8	1,042.3
Entergy Louisiana [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		57.6	34.8
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,510.1	1,379.2
Entergy Louisiana [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0.4	7
Entergy Louisiana [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	5.7	7.1
Entergy Louisiana [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	440.1	409.9
Entergy Louisiana [Member] | Common trust funds valued using Net Asset Value [Domain] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	679	625.3
Entergy Louisiana [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		305.5	290.4
Entergy Louisiana [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		9.8	3.2
Entergy Louisiana [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		12.4	8.5
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		57.6	34.8
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		510.1	496.6
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0.4	7
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	5.7	7.1
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	131.5	161.1
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		305.5	290.4
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		9.8	3.2
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		308.6	248.8
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	308.6	248.8
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		12.4	8.5
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		12.4	8.5
Entergy Arkansas [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		823.8	771.3
Entergy Arkansas [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		846.7	795.6
Entergy Arkansas [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	3.7	3
Entergy Arkansas [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	318.9	303.9
Entergy Arkansas [Member] | Common trust funds valued using Net Asset Value [Domain] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	501.2	464.4
Entergy Arkansas [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		7.1	12.2
Entergy Arkansas [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		7.7	4.2
Entergy Arkansas [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		8.1	7.9
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		121.6	129.9
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	3.7	3
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	103.1	110.5
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		7.1	12.2
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		7.7	4.2
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		215.8	193.4
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	215.8	193.4
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		8.1	7.9
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		8.1	7.9
Entergy Mississippi [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		307.3	144.2
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		343.1	188.3
Entergy Mississippi [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0.1	1.3
Entergy Mississippi [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		31.8	41.7
Entergy Mississippi [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		4	2.4
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		307.3	144.2
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		339.1	185.9
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0.1	1.3
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		31.8	41.7
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		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] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		4	2.4
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		4	2.4
Entergy New Orleans [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		37.2	87.8
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		132.3	174.9
Entergy New Orleans [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0.5
Entergy New Orleans [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		88.4	81
Entergy New Orleans [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		5.1	4.6
Entergy New Orleans [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		1.6	1.5
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		37.2	87.8
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		130.7	173.4
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0.5
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		88.4	81
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		5.1	4.6
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		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] | Fair Value, Measurements, Recurring [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] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1.6	1.5
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [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] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		1.6	1.5
Entergy Texas [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		36.5	40.4
Entergy Texas [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		31.4	38.2
Entergy Texas [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		5.1	2.2
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		31.4	38.2
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		31.4	38.2
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		5.1	2.2
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		5.1	2.2
System Energy [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		764.9	701.5
System Energy [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		190.2	222
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		955.1	923.5
System Energy [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	1.2	1.8
System Energy [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	308.6	277.8
System Energy [Member] | Common trust funds valued using Net Asset Value [Domain] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	455.1	421.9
System Energy [Member] | Fair Value Inputs Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		190.2	222
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		437.9	442.4
System Energy [Member] | Fair Value Inputs Level 1 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	1.2	1.8
System Energy [Member] | Fair Value Inputs Level 1 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	246.5	218.6
System Energy [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		62.1	59.2
System Energy [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	0	0
System Energy [Member] | Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	62.1	59.2
System Energy [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0	0
System Energy [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	0	0
System Energy [Member] | Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	$ 0	$ 0
[1]	(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements herein for additional information on the investment portfolios.
[2]	(b)Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.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, 2016 and 2015: 2016 2015 Power Contracts FTRs Power Contracts FTRs (In Millions)Balance as of July 1,$66 $46 $204 $67Total gains (losses) for the period (a) Included in earnings6 — (2) —Included in OCI70 — 49 —Included as a regulatory liability/asset— 22 — 31Settlements(47) (37) (88) (51)Balance as of September 30,$95 $31 $163 $47
[3]	(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements herein for additional information on the investment portfolios.(b)Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

Risk Management and Fair Valu58

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, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Issuance of Fixed Transmission Rights			$ 0	$ 0
Electricity Swaps And Options [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	$ 66	$ 204	189	215
Total gains (losses) for the period (a)	6	(2)	(3)	(15)
Unrealized losses included in OCI	70	49	156	154
Included as a regulatory liability/asset	0	0	0	0
Purchases			0	14
Settlements	(47)	(88)	(247)	(205)
Balance as of September 30,	95	163	95	163
Fixed Transmission Rights (FTRs) [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	46	67	23	47
Total gains (losses) for the period (a)	0	0	0	(1)
Unrealized losses included in OCI	0	0	0	0
Included as a regulatory liability/asset	22	31	49	51
Issuance of Fixed Transmission Rights			55	80
Purchases			0	0
Settlements	(37)	(51)	(96)	(130)
Balance as of September 30,	31	47	31	47
Fixed Transmission Rights (FTRs) [Member] | Entergy Arkansas [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	14	9.1	7.9	0.7
Issuance of Fixed Transmission Rights			18.8	7
Unrealized gains included as a regulatory liability/asset	1.2	16.5	1.7	52.6
Settlements	(7.1)	(13.9)	(20.3)	(48.6)
Balance as of September 30,	8.1	11.7	8.1	11.7
Fixed Transmission Rights (FTRs) [Member] | Entergy Louisiana [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	16.2	37.3	8.5	25.5
Issuance of Fixed Transmission Rights			18.1	48.3
Unrealized gains included as a regulatory liability/asset	16.6	3	38.3	(1.7)
Settlements	(20.4)	(17.9)	(52.5)	(49.7)
Balance as of September 30,	12.4	22.4	12.4	22.4
Fixed Transmission Rights (FTRs) [Member] | Entergy Mississippi [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	5.6	4.9	2.4	3.4
Issuance of Fixed Transmission Rights			5.9	5.4
Unrealized gains included as a regulatory liability/asset	5.1	6.1	6.8	9.4
Settlements	(6.7)	(6.7)	(11.1)	(13.9)
Balance as of September 30,	4	4.3	4	4.3
Fixed Transmission Rights (FTRs) [Member] | Entergy New Orleans [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	2	6.7	1.5	4.1
Issuance of Fixed Transmission Rights			2.8	7.3
Unrealized gains included as a regulatory liability/asset	0.5	(1.2)	0.1	0.1
Settlements	(0.9)	(1.5)	(2.8)	(7.5)
Balance as of September 30,	1.6	4	1.6	4
Fixed Transmission Rights (FTRs) [Member] | Entergy Texas [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	8	7.9	2.2	12.3
Issuance of Fixed Transmission Rights			9.3	11.4
Unrealized gains included as a regulatory liability/asset	(1.1)	7.3	2.3	(8.7)
Settlements	(1.8)	(10.9)	(8.7)	(10.7)
Balance as of September 30,	$ 5.1	$ 4.3	$ 5.1	$ 4.3

Risk Management and Fair Valu59

Risk Management and Fair Values (Schedules Of Valuation Techniques) (Details) $ in Millions	Sep. 30, 2016USD ($)
Range From Average Percentage for Electricity Options	9.00%
Range from Average Percentage for Fair Value of Electricity Swaps	4.00%
Effect of Significant Unobservable Inputs on Fair Value of Electricity Swaps	$ 7
Effect of Significant Unobservable Inputs on Fair Value of Electricity Options	4
Fair Value of Electricity Options	5
Fair Value of Electricity Swaps	$ 90

Decommissioning Trust Funds (Na

Decommissioning Trust Funds (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Decommissioning Trust Funds [Abstract]
Receivables recorded for beneficial interests in decommissioning trust funds	$ 1,500,000		$ 1,500,000
Decommissioning Fund Investments	5,671,074		5,671,074		$ 5,349,953
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts			400,000		342,000
Amortized cost of debt securities	$ 2,199,000		$ 2,199,000		2,124,000
Average coupon rate of debt securities	3.19%		3.19%
Average duration of debt securities, years			5 years 11 months 14 days
Average maturity of debt securities, years			9 years 4 months 22 days
Proceeds from the dispositions of debt securities	$ 564,000	$ 539,000	$ 1,797,000	$ 1,488,000
Gains from dispositions of debt securities, gross	6,000	13,000	26,000	58,000
Losses from dispositions of debt securities, gross	1,000	4,000	6,000	7,000
Entergy Arkansas [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments	823,816		823,816		771,313
Amortized cost of debt securities	$ 308,400		$ 308,400		301,800
Average coupon rate of debt securities	2.63%		2.63%
Average duration of debt securities, years			5 years 2 months 17 days
Average maturity of debt securities, years			5 years 11 months 20 days
Proceeds from the dispositions of debt securities	$ 61,200	44,000	$ 165,000	190,800
Gains from dispositions of debt securities, gross	400	400	1,600	5,800
Losses from dispositions of debt securities, gross	40	100	300	100
Entergy Louisiana [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments	1,124,821		$ 1,124,821		1,042,293
Percentage Interest in River Bend			30.00%
Amortized cost of debt securities	$ 419,200		$ 419,200		399,200
Average coupon rate of debt securities	3.83%		3.83%
Average duration of debt securities, years			5 years 8 months 20 days
Average maturity of debt securities, years			11 years 4 months 22 days
Proceeds from the dispositions of debt securities	$ 54,700	28,400	$ 178,200	93,600
Gains from dispositions of debt securities, gross	400	200	3,000	1,700
Losses from dispositions of debt securities, gross	100	100	200	300
System Energy [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments	764,903		764,903		701,460
Amortized cost of debt securities	$ 302,300		$ 302,300		$ 270,700
Average coupon rate of debt securities	1.79%		1.79%
Average duration of debt securities, years			5 years 2 months 6 days
Average maturity of debt securities, years			6 years 3 months 27 days
Proceeds from the dispositions of debt securities	$ 103,500	163,400	$ 392,900	325,400
Gains from dispositions of debt securities, gross	700	2,400	3,200	3,200
Losses from dispositions of debt securities, gross	60	$ 200	400	$ 300
NYPA [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments	$ 1,500,000		$ 1,500,000

Decommissioning Trust Funds (Se

Decommissioning Trust Funds (Securities Held) (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Schedule of Available-for-sale Securities [Line Items]
Fair Value	$ 5,671	$ 5,350
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	1,662	1,437
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	3	19
Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	3,380	3,195
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	1,568	1,396
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	1	2
Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	2,291	2,155
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	94	41
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	2	17
Entergy Arkansas [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	823.8	771.3
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	274.2	238.5
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.3	2.4
Entergy Arkansas [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	504.9	467.4
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	263.4	234.4
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0	0.2
Entergy Arkansas [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	318.9	303.9
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	10.8	4.1
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.3	2.2
Entergy Louisiana [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	1,124.8	1,042.3
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	344.3	296.9
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.4	2.6
Entergy Louisiana [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	684.7	632.4
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	322.9	283.7
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0	0.2
Entergy Louisiana [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	440.1	409.9
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	21.4	13.2
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.4	2.4
System Energy [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	764.9	701.5
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	212.2	181.4
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.4	2.6
System Energy [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	456.3	423.7
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	205.5	179.2
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.1	0.3
System Energy [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	308.6	277.8
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	6.7	2.2
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	$ 0.3	$ 2.3

Decommissioning Trust Funds (Av

Decommissioning Trust Funds (Available For Sale Securities Continuous Unrealized Loss Position Fair Value) (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	$ 13	$ 54
More than 12 months Fair Value	0	1
Total Fair Value	13	55
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	1	2
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0	0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	1	2
Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	266	1,031
More than 12 months Fair Value	23	61
Total Fair Value	289	1,092
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	1	15
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	1	2
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	2	17
Entergy Arkansas [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	0.9	7.8
More than 12 months Fair Value	0	0
Total Fair Value	0.9	7.8
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0	0.2
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0	0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	0	0.2
Entergy Arkansas [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	32.5	111.4
More than 12 months Fair Value	0	18.5
Total Fair Value	32.5	129.9
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0.3	1.7
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0	0.5
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	0.3	2.2
Entergy Louisiana [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	2.3	9.4
More than 12 months Fair Value	0	0
Total Fair Value	2.3	9.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0	0.2
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0	0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	0	0.2
Entergy Louisiana [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	32.5	124
More than 12 months Fair Value	6.5	7.4
Total Fair Value	39	131.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0.2	2
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.2	0.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	0.4	2.4
System Energy [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	0.8	8.3
More than 12 months Fair Value	0	0.9
Total Fair Value	0.8	9.2
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0	0.2
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.1	0.1
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	0.1	0.3
System Energy [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	81.4	200.4
More than 12 months Fair Value	1	5
Total Fair Value	82.4	205.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0.2	2.2
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.1	0.1
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	$ 0.3	$ 2.3

Decommissioning Trust Funds (Fa

Decommissioning Trust Funds (Fair Value Of Debt Securities By Contractual Maturities) (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Fair value of debt securities by contractual maturities
Less than 1 year	$ 102	$ 77
1 year - 5 years	812	857
5 years - 10 years	743	704
10 years - 15 years	128	124
15 years - 20 years	62	50
20 years+	444	343
Total	2,291	2,155
Entergy Arkansas [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	8.8	1.8
1 year - 5 years	123.5	145.2
5 years - 10 years	166.1	138.5
10 years - 15 years	9.5	2.4
15 years - 20 years	1.1	2
20 years+	9.9	14
Total	318.9	303.9
Entergy Louisiana [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	25	27.1
1 year - 5 years	102.3	124
5 years - 10 years	121.5	114.3
10 years - 15 years	51	39.3
15 years - 20 years	31.1	26.5
20 years+	109.2	78.7
Total	440.1	409.9
System Energy [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	3	2
1 year - 5 years	192.6	181.2
5 years - 10 years	76.2	63
10 years - 15 years	3.5	4.4
15 years - 20 years	1.5	1.6
20 years+	31.8	25.6
Total	$ 308.6	$ 277.8

Income Taxes Income Taxes (Narr

Income Taxes Income Taxes (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended	9 Months Ended
	Jun. 30, 2016	Sep. 30, 2016	Dec. 31, 2015
Regulatory Liability, Noncurrent		$ 1,525,897	$ 1,414,898
Income tax benefit resulting from 2010-2011 IRS audit associated with Act 55 financing	$ 63,500
Reduction in income tax expense related to permanent difference for nuclear decommissioning liability, net of unrecognized tax benefits		238,000
Entergy Arkansas [Member]
Regulatory Liability, Noncurrent		292,545	242,913
Entergy Louisiana [Member]
Proceeds received from LURC related to Act 55 financing not taxable	148,600
Regulatory Liability, Noncurrent		849,470	818,623
Unrecognized Tax Benefits	564,700		796,900
Income tax benefit resulting from 2010-2011 IRS audit associated with Act 55 financing	61,600
Income tax benefit resulting from 2010-2011 IRS audit related to Vidalia purchased power agreement	74,500
Regulatory liability for customer savings associated with Act 55 financing	16,100
Regulatory liability for customer savings associated with Act 55 financing, net of tax	$ 9,900
System Energy [Member]
Regulatory Liability, Noncurrent		$ 365,302	$ 337,424

Property, Plant, And Equipment

Property, Plant, And Equipment (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended		3 Months Ended		9 Months Ended
	Mar. 31, 2016	Dec. 31, 2014	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Construction expenditures in accounts payable			$ 175,800		$ 175,800		$ 234,000
Impairment of Long-Lived Assets Held-for-use					33,170	$ 1,642,204
Asset Write-Offs, Impairments, And Related Charges			18,841	$ 1,642,204	33,170	$ 1,642,204
Entergy Arkansas [Member]
Construction expenditures in accounts payable			21,700		21,700		43,000
Entergy Louisiana [Member]
Construction expenditures in accounts payable			75,500		75,500		68,600
Impairment of Long-Lived Assets Held-for-use		$ 16,000
Cash payment representing the purchase price to acquire the undivided interests in Waterford 3	$ 60,000
Portion of Waterford 3 purchase price satisfied through issuance of debt	$ 52,000
Entergy Mississippi [Member]
Construction expenditures in accounts payable			4,500		4,500		11,400
Entergy New Orleans [Member]
Construction expenditures in accounts payable			1,000		1,000		1,500
Entergy Texas [Member]
Construction expenditures in accounts payable			8,000		8,000		33,100
System Energy [Member]
Construction expenditures in accounts payable			$ 12,700		$ 12,700		$ 6,800

Variable Interest Entities (Nar

Variable Interest Entities (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Waterford Three [Member] | Entergy Louisiana [Member]
Variable Interest Entity [Line Items]
Payments on lease, including interest	$ 7.8	$ 7.8	$ 16.9	$ 28.8
Percentage In Power Plant Previously Owned By VIE			9.30%
Grand Gulf [Member] | System Energy [Member]
Variable Interest Entity [Line Items]
Payments on lease, including interest	$ 8.6	$ 14.6	$ 17.2	$ 52.3
Percentage in power plant owned by VIE			11.50%

Acquisitions Acquisitions (Narr

Acquisitions Acquisitions (Narrative) (Details) $ in Thousands	1 Months Ended	9 Months Ended
	Mar. 31, 2016USD ($)MW	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)
Payments to Acquire Property, Plant, and Equipment		$ (949,329)	$ 0
Union Power Station [Member]
Capacity Per Power Block | MW	495
Payments to Acquire Property, Plant, and Equipment	$ (949,000)
Capacity Of Power Plant Unit | MW	1,980
Entergy Arkansas [Member]
Payments to Acquire Property, Plant, and Equipment	$ (237,000)	(237,324)	0
Entergy Arkansas [Member] | Union Power Station [Member]
Percentage of Undivided Ownership Interest	25.00%
Payments to Acquire Property, Plant, and Equipment	$ (237,324)
Power Blocks Purchased	1
Entergy Louisiana [Member]
Payments to Acquire Property, Plant, and Equipment	$ (474,000)	(474,670)	0
Entergy Louisiana [Member] | Union Power Station [Member]
Percentage of Undivided Ownership Interest	50.00%
Payments to Acquire Property, Plant, and Equipment	$ (474,670)
Power Blocks Purchased	2
Entergy New Orleans [Member]
Payments to Acquire Property, Plant, and Equipment	$ (237,000)	$ (237,335)	$ 0
Entergy New Orleans [Member] | Union Power Station [Member]
Percentage of Undivided Ownership Interest	25.00%
Payments to Acquire Property, Plant, and Equipment	$ (237,335)
Power Blocks Purchased	1

Asset Retirement Obligations (N

Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended
	Jun. 30, 2015	Sep. 30, 2016	Dec. 31, 2015
Asset Retirement Obligations, Noncurrent		$ 6,101,283	$ 4,790,187
Entergy Wholesale Commodities [Member] | Vermont Yankee [Member]
NRC allowed future spent fuel management costs to be paid from Vermont Yankee decommissioning trust fund	$ 225,000