Entergy Texas (ETI-P) 10-Q 6 May 16 2016 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2016	Apr. 29, 2016
Entity Registrant Name	ENTERGY CORP /DE/
Entity Central Index Key	65,984
Document Type	10-Q
Document Period End Date	Mar. 31, 2016
Amendment Flag	false
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q1
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		178,740,867
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
		Mar. 31, 2016	Mar. 31, 2015
OPERATING REVENUES
Electric		$ 2,042,160	$ 2,217,989
Natural gas		45,613	59,511
Competitive businesses		522,079	642,590
TOTAL		2,609,852	2,920,090
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		504,967	630,453
Purchased power		262,323	342,023
Nuclear refueling outage expenses		51,230	64,870
Other operation and maintenance		731,915	770,110
Asset Write-Offs, Impairments, And Related Charges		7,361	0
Decommissioning		68,628	69,899
Taxes other than income taxes		149,778	157,523
Depreciation and amortization		334,273	331,986
Other regulatory charges (credits) - net		1,159	10,457
TOTAL		2,111,634	2,377,321
OPERATING INCOME		498,218	542,769
OTHER INCOME
Allowance for equity funds used during construction		18,932	11,738
Investment Income, Net		32,753	68,133
Miscellaneous - net		(10,587)	(9,020)
TOTAL		41,098	70,851
INTEREST EXPENSE
Interest expense		173,811	166,337
Allowance for borrowed funds used during construction		(9,682)	(6,117)
TOTAL		164,129	160,220
INCOME BEFORE INCOME TAXES		375,187	453,400
Income taxes		139,945	150,471
CONSOLIDATED NET INCOME	[1]	235,242	302,929
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders		5,276	4,879
EARNINGS APPLICABLE TO COMMON STOCK		$ 229,966	$ 298,050
Earnings per average common share:
Basic (in dollars per share)		$ 1.29	$ 1.66
Diluted (in dollars per share)		1.28	1.65
Dividends declared per common share (in dollars per share)		$ 0.85	$ 0.83
Basic average number of common shares outstanding (in shares)		178,578,536	179,658,981
Diluted average number of common shares outstanding (in shares)		178,976,380	180,480,523
Entergy Arkansas [Member]
OPERATING REVENUES
Electric		$ 465,373	$ 511,253
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		80,937	104,872
Purchased power		61,804	99,814
Nuclear refueling outage expenses		15,069	12,063
Other operation and maintenance		152,906	160,545
Decommissioning		13,103	12,304
Taxes other than income taxes		23,086	25,704
Depreciation and amortization		63,173	60,102
Other regulatory charges (credits) - net		917	(807)
TOTAL		410,995	474,597
OPERATING INCOME		54,378	36,656
OTHER INCOME
Allowance for equity funds used during construction		4,932	2,374
Interest and investment income			10,952
Investment Income, Net		3,594
Miscellaneous - net		(775)	(167)
TOTAL		7,751	13,159
INTEREST EXPENSE
Interest expense		32,782	26,487
Allowance for borrowed funds used during construction		(2,715)	(1,231)
TOTAL		30,067	25,256
INCOME BEFORE INCOME TAXES		32,062	24,559
Income taxes		12,768	6,694
CONSOLIDATED NET INCOME		19,294	17,865
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders		1,718	1,718
EARNINGS APPLICABLE TO COMMON STOCK		17,576	16,147
Entergy Louisiana [Member]
OPERATING REVENUES
Electric		936,431	1,044,810
Natural gas		18,714	24,381
TOTAL		955,145	1,069,191
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		202,083	219,658
Purchased power		191,398	271,198
Nuclear refueling outage expenses		12,780	11,130
Other operation and maintenance		206,064	220,801
Decommissioning		11,508	10,645
Taxes other than income taxes		42,362	43,890
Depreciation and amortization		109,591	106,868
Other regulatory charges (credits) - net		(2,259)	(775)
TOTAL		773,527	883,415
OPERATING INCOME		181,618	185,776
OTHER INCOME
Allowance for equity funds used during construction		7,238	5,472
Investment Income, Net		37,416	40,016
Miscellaneous - net		(3,745)	(200)
TOTAL		40,909	45,288
INTEREST EXPENSE
Interest expense		65,076	65,281
Allowance for borrowed funds used during construction		(3,897)	(3,128)
TOTAL		61,179	62,153
INCOME BEFORE INCOME TAXES		161,348	168,911
Income taxes		49,742	42,802
CONSOLIDATED NET INCOME		111,606	126,109
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders		0	1,944
EARNINGS APPLICABLE TO COMMON STOCK		111,606	124,165
Entergy Mississippi [Member]
OPERATING REVENUES
Electric		263,046	360,815
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		61,380	90,611
Purchased power		55,383	92,158
Other operation and maintenance		51,273	65,072
Taxes other than income taxes		23,497	25,020
Depreciation and amortization		33,298	30,830
Other regulatory charges (credits) - net		(3,358)	2,285
TOTAL		221,473	305,976
OPERATING INCOME		41,573	54,839
OTHER INCOME
Allowance for equity funds used during construction		1,286	771
Investment Income, Net		121	28
Miscellaneous - net		(705)	(802)
TOTAL		702	(3)
INTEREST EXPENSE
Interest expense		14,742	14,246
Allowance for borrowed funds used during construction		(667)	(417)
TOTAL		14,075	13,829
INCOME BEFORE INCOME TAXES		28,200	41,007
Income taxes		11,082	16,072
CONSOLIDATED NET INCOME		17,118	24,935
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders		707	707
EARNINGS APPLICABLE TO COMMON STOCK		16,411	24,228
Entergy New Orleans [Member]
OPERATING REVENUES
Electric		122,441	121,495
Natural gas		26,899	35,131
TOTAL		149,340	156,626
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		10,921	21,623
Purchased power		68,525	63,135
Other operation and maintenance		22,842	28,000
Taxes other than income taxes		11,512	11,893
Depreciation and amortization		11,764	11,520
Other regulatory charges (credits) - net		1,896	(290)
TOTAL		127,460	135,881
OPERATING INCOME		21,880	20,745
OTHER INCOME
Allowance for equity funds used during construction		313	320
Investment Income, Net		69	26
Miscellaneous - net		(245)	364
TOTAL		137	710
INTEREST EXPENSE
Interest expense		4,373	4,341
Allowance for borrowed funds used during construction		(126)	(150)
TOTAL		4,247	4,191
INCOME BEFORE INCOME TAXES		17,770	17,264
Income taxes		6,603	5,972
CONSOLIDATED NET INCOME		11,167	11,292
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders		241	241
EARNINGS APPLICABLE TO COMMON STOCK		10,926	11,051
Entergy Texas [Member]
OPERATING REVENUES
Electric		378,304	411,211
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		92,404	73,807
Purchased power		130,412	174,205
Other operation and maintenance		53,035	56,525
Taxes other than income taxes		18,310	18,270
Depreciation and amortization		25,619	24,847
Other regulatory charges (credits) - net		17,255	19,544
TOTAL		337,035	367,198
OPERATING INCOME		41,269	44,013
OTHER INCOME
Allowance for equity funds used during construction		2,432	1,224
Investment Income, Net		200	(213)
Miscellaneous - net		(416)	64
TOTAL		2,216	1,075
INTEREST EXPENSE
Interest expense		21,601	20,996
Allowance for borrowed funds used during construction		(1,581)	(794)
TOTAL		20,020	20,202
INCOME BEFORE INCOME TAXES		23,465	24,886
Income taxes		8,903	8,295
CONSOLIDATED NET INCOME		14,562	16,591
System Energy [Member]
OPERATING REVENUES
Electric		137,693	156,039
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		13,428	20,473
Nuclear refueling outage expenses		4,584	5,682
Other operation and maintenance		32,160	35,706
Decommissioning		12,387	11,703
Taxes other than income taxes		6,252	7,208
Depreciation and amortization		34,707	37,060
Other regulatory charges (credits) - net		(13,291)	(9,577)
TOTAL		90,227	108,255
OPERATING INCOME		47,466	47,784
OTHER INCOME
Allowance for equity funds used during construction		2,729	1,651
Investment Income, Net		3,274	4,213
Miscellaneous - net		(92)	(221)
TOTAL		5,911	5,643
INTEREST EXPENSE
Interest expense		9,552	13,013
Allowance for borrowed funds used during construction		(696)	(436)
TOTAL		8,856	12,577
INCOME BEFORE INCOME TAXES		44,521	40,850
Income taxes		18,563	15,317
CONSOLIDATED NET INCOME		$ 25,958	$ 25,533
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $5.3 million and $3.2 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		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
OPERATING ACTIVITIES
Consolidated net income	[1]	$ 235,242	$ 302,929
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		500,248	526,008
Deferred income taxes, investment tax credits, and non-current taxes accrued		75,415	95,732
Impairment of Long-Lived Assets Held-for-use		7,361	0
Changes in working capital:
Receivables		76,532	22,288
Fuel inventory		(9,089)	(22,553)
Accounts payable		(67,364)	(153,700)
Taxes accrued		(15,996)	(67,941)
Interest accrued		(27,535)	(42,551)
Deferred fuel costs		97,566	81,271
Other working capital accounts		(95,291)	(90,619)
Changes in provisions for estimated losses		(3,968)	1,334
Changes in other regulatory assets		56,047	93,082
Changes in other regulatory liabilities		18,735	15,857
Changes in pensions and other postretirement liabilities		(89,046)	(52,509)
Other		(226,036)	(97,670)
Net cash flow provided by operating activities		532,821	610,958
INVESTING ACTIVITIES
Construction/capital expenditures		(636,011)	(532,958)
Allowance for equity funds used during construction		19,107	13,077
Payments to Acquire Property, Plant, and Equipment		(947,778)	0
Nuclear fuel purchases		(85,819)	(96,392)
NYPA value sharing payment		0	(70,790)
Payments to storm reserve escrow account		(367)	(1,865)
Decrease (increase) in other investments		(196,509)	278
Proceeds from nuclear decommissioning trust fund sales		729,414	492,841
Investment in nuclear decommissioning trust funds		(758,665)	(516,564)
Proceeds from insurance		0	12,745
Changes in securitization account		(1,399)	(251)
Net cash flow used in investing activities		(1,878,027)	(699,879)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		2,869,808	488,065
Common stock and treasury stock		5,787	23,156
Retirement of long-term debt		(1,903,670)	(685,258)
Payments for Repurchase of Common Stock		0	(25,078)
Changes in credit borrowings and commercial paper - net		271,730	210,012
Dividends paid:
Common stock		(151,839)	(149,257)
Preferred stock		(5,276)	(4,879)
Other		(644)	(9,320)
Net cash flow provided by (used in) financing activities		1,085,896	(152,559)
Net decrease in cash and cash equivalents		(259,310)	(241,480)
Cash and cash equivalents at beginning of period		1,350,961	1,422,026
Cash and cash equivalents at end of period		1,091,651	1,180,546
Cash paid / (received) during the period for:
Interest - net of amount capitalized		251,305	203,786
Income taxes		26,382	65,919
Entergy Arkansas [Member]
OPERATING ACTIVITIES
Consolidated net income		19,294	17,865
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		102,975	97,294
Deferred income taxes, investment tax credits, and non-current taxes accrued		20,645	17,847
Changes in working capital:
Receivables		(4,405)	(8,086)
Fuel inventory		(5,825)	(8,232)
Accounts payable		55,077	(24,651)
Taxes accrued		1,210	(18,923)
Interest accrued		5,228	4,338
Deferred fuel costs		(37,198)	14,933
Other working capital accounts		15,203	(27,858)
Changes in provisions for estimated losses		355	46
Changes in other regulatory assets		892	29,585
Changes in pensions and other postretirement liabilities		(24,288)	(19,074)
Other		(9,550)	(6,165)
Net cash flow provided by operating activities		139,613	68,919
INVESTING ACTIVITIES
Construction/capital expenditures		(171,090)	(128,399)
Allowance for equity funds used during construction		5,080	3,700
Payments to Acquire Property, Plant, and Equipment		(236,947)	0
Change in money pool receivable - net		(1,842)	(13,001)
Nuclear fuel purchases		(22,692)	(21,392)
Proceeds from sale of nuclear fuel		40,336	28,296
Proceeds from nuclear decommissioning trust fund sales		58,604	81,852
Investment in nuclear decommissioning trust funds		(63,039)	(85,620)
Changes in securitization account		(3,413)	(3,973)
Other		(103)	0
Net cash flow used in investing activities		(395,106)	(138,537)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		321,289	0
Proceeds from Contributions from Parent		200,000	0
Retirement of long-term debt		(175,002)	0
Change in money pool payable - net		(52,742)	0
Changes in credit borrowings and commercial paper - net		(11,690)	(28,462)
Dividends paid:
Preferred stock		(1,718)	(1,718)
Other		0	783
Net cash flow provided by (used in) financing activities		280,137	(29,397)
Net decrease in cash and cash equivalents		24,644	(99,015)
Cash and cash equivalents at beginning of period		9,135	218,505
Cash and cash equivalents at end of period		33,779	119,490
Cash paid / (received) during the period for:
Interest - net of amount capitalized		20,998	20,761
Income taxes		7,242	17,587
Entergy Louisiana [Member]
OPERATING ACTIVITIES
Consolidated net income		111,606	126,109
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		146,870	145,069
Deferred income taxes, investment tax credits, and non-current taxes accrued		172,887	60,884
Changes in working capital:
Receivables		(25,879)	(49,211)
Fuel inventory		(2,538)	(3,153)
Accounts payable		(110,500)	7,886
Taxes accrued		(104,444)	14,463
Interest accrued		(2,185)	717
Deferred fuel costs		45,511	14,633
Other working capital accounts		1,387	(25,286)
Changes in provisions for estimated losses		(2,695)	2,329
Changes in other regulatory assets		30,033	22,417
Changes in pensions and other postretirement liabilities		(19,115)	(10,720)
Other		(92,457)	(24,400)
Net cash flow provided by operating activities		148,481	281,737
INVESTING ACTIVITIES
Construction/capital expenditures		(206,572)	(180,634)
Allowance for equity funds used during construction		7,238	5,472
Payments to Acquire Property, Plant, and Equipment		(473,888)	0
Change in money pool receivable - net		(7,559)	(35,011)
Change in Assets Held-In Trust		(196,568)	0
Nuclear fuel purchases		(26,684)	(108,613)
Proceeds from sale of nuclear fuel		47,565	18,123
Payments to storm reserve escrow account		0	(19)
Proceeds from nuclear decommissioning trust fund sales		53,793	25,566
Investment in nuclear decommissioning trust funds		(64,337)	(35,579)
Changes in securitization account		(5,506)	(5,433)
Other		(243)	(41)
Net cash flow used in investing activities		(872,761)	(316,169)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		809,369	0
Retirement of long-term debt		(26,189)	(16,083)
Changes in credit borrowings and commercial paper - net		17,094	22,260
Dividends paid:
Preferred stock		0	(1,944)
Other		852	(7,731)
Net cash flow provided by (used in) financing activities		801,126	(3,498)
Net decrease in cash and cash equivalents		76,846	(37,930)
Cash and cash equivalents at beginning of period		35,102	320,516
Cash and cash equivalents at end of period		111,948	282,586
Cash paid / (received) during the period for:
Interest - net of amount capitalized		125,589	62,655
Income taxes		22,676	(4,056)
Entergy Mississippi [Member]
OPERATING ACTIVITIES
Consolidated net income		17,118	24,935
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		33,298	30,830
Deferred income taxes, investment tax credits, and non-current taxes accrued		(7,095)	(51,789)
Changes in working capital:
Receivables		(5,118)	20,385
Fuel inventory		(3,244)	(4,628)
Accounts payable		(3,329)	(12,413)
Taxes accrued		(24,009)	21,501
Interest accrued		(2,033)	(6,218)
Deferred fuel costs		40,350	40,244
Other working capital accounts		(979)	(997)
Changes in provisions for estimated losses		(2,016)	(157)
Changes in other regulatory assets		751	15,065
Changes in pensions and other postretirement liabilities		(6,015)	(4,153)
Other		(7,403)	(7,438)
Net cash flow provided by operating activities		30,276	65,167
INVESTING ACTIVITIES
Construction/capital expenditures		(72,764)	(45,976)
Allowance for equity funds used during construction		1,286	771
Change in money pool receivable - net		10,381	(9,878)
Proceeds from insurance		0	12,745
Other		(81)	(2)
Net cash flow used in investing activities		(61,178)	(42,340)
Dividends paid:
Preferred stock		(707)	(707)
Other		(50)	(42)
Net cash flow provided by (used in) financing activities		(757)	(749)
Net decrease in cash and cash equivalents		(31,659)	22,078
Cash and cash equivalents at beginning of period		145,605	61,633
Cash and cash equivalents at end of period		113,946	83,711
Cash paid / (received) during the period for:
Interest - net of amount capitalized		16,137	19,813
Income taxes		(6,175)	597
Entergy New Orleans [Member]
OPERATING ACTIVITIES
Consolidated net income		11,167	11,292
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		11,764	11,520
Deferred income taxes, investment tax credits, and non-current taxes accrued		(9,742)	4,883
Changes in working capital:
Receivables		(5,346)	4,474
Fuel inventory		1,518	1,360
Accounts payable		(101)	(3,829)
Taxes accrued		14,187	0
Interest accrued		(579)	(1,315)
Deferred fuel costs		(5,288)	(3,949)
Other working capital accounts		(11,382)	(9,271)
Changes in provisions for estimated losses		(532)	(2,012)
Changes in other regulatory assets		6,270	(676)
Changes in pensions and other postretirement liabilities		(4,102)	(3,013)
Other		(3,381)	(2,237)
Net cash flow provided by operating activities		4,453	7,227
INVESTING ACTIVITIES
Construction/capital expenditures		(17,931)	(16,110)
Allowance for equity funds used during construction		313	320
Payments to Acquire Property, Plant, and Equipment		(236,944)	0
Proceeds from Divestiture of Businesses and Interests in Affiliates		(38)	0
Change in money pool receivable - net		15,059	(2,407)
Payments to storm reserve escrow account		(102)	(1,806)
Receipts from storm reserve escrow account		3	3
Changes in securitization account		(2,746)	0
Net cash flow used in investing activities		(242,386)	(20,000)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		106,786	0
Proceeds from Contributions from Parent		47,750	0
Dividends paid:
Common stock		0	(7,250)
Preferred stock		(241)	(241)
Other		730	(75)
Net cash flow provided by (used in) financing activities		155,025	(7,566)
Net decrease in cash and cash equivalents		(82,908)	(20,339)
Cash and cash equivalents at beginning of period		88,876	42,389
Cash and cash equivalents at end of period		5,968	22,050
Cash paid / (received) during the period for:
Interest - net of amount capitalized		4,654	5,405
Income taxes		2,500	40
Entergy Texas [Member]
OPERATING ACTIVITIES
Consolidated net income		14,562	16,591
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		25,619	24,847
Deferred income taxes, investment tax credits, and non-current taxes accrued		(26,970)	(75,378)
Changes in working capital:
Receivables		2,118	22,233
Fuel inventory		2,860	(3,976)
Accounts payable		(17,346)	(14,776)
Taxes accrued		18,871	66,279
Interest accrued		(9,978)	(8,952)
Deferred fuel costs		54,192	15,517
Other working capital accounts		1,957	4,686
Changes in provisions for estimated losses		662	1,252
Changes in other regulatory assets		24,310	26,065
Changes in pensions and other postretirement liabilities		(6,505)	(4,387)
Other		(8,617)	(3,676)
Net cash flow provided by operating activities		75,735	66,325
INVESTING ACTIVITIES
Construction/capital expenditures		(91,843)	(66,371)
Allowance for equity funds used during construction		2,460	1,237
Change in money pool receivable - net		(8,938)	(1,532)
Changes in securitization account		10,264	9,155
Net cash flow used in investing activities		(88,057)	(57,511)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		123,786	0
Retirement of long-term debt		(23,458)	(22,769)
Change in money pool payable - net		(22,068)	0
Dividends paid:
Other		(1,787)	(974)
Net cash flow provided by (used in) financing activities		76,473	(23,743)
Net decrease in cash and cash equivalents		64,151	(14,929)
Cash and cash equivalents at beginning of period		2,182	30,441
Cash and cash equivalents at end of period		66,333	15,512
Cash paid / (received) during the period for:
Interest - net of amount capitalized		30,969	29,004
Income taxes		(756)	(933)
System Energy [Member]
OPERATING ACTIVITIES
Consolidated net income		25,958	25,533
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		58,717	66,660
Deferred income taxes, investment tax credits, and non-current taxes accrued		49,894	(10,618)
Changes in working capital:
Receivables		9,121	2,952
Accounts payable		16,257	(6,919)
Taxes accrued		(38,617)	(14,444)
Interest accrued		837	(14,282)
Other working capital accounts		(30,111)	600
Changes in other regulatory assets		(8,319)	(2,493)
Changes in pensions and other postretirement liabilities		(4,576)	(3,188)
Other		(6,005)	(4,082)
Net cash flow provided by operating activities		73,156	39,719
INVESTING ACTIVITIES
Construction/capital expenditures		(34,747)	(13,324)
Allowance for equity funds used during construction		2,729	1,651
Change in money pool receivable - net		4,728	(20,873)
Nuclear fuel purchases		(122,320)	(16,699)
Proceeds from sale of nuclear fuel		0	22,563
Proceeds from nuclear decommissioning trust fund sales		188,506	78,361
Investment in nuclear decommissioning trust funds		(197,996)	(86,832)
Net cash flow used in investing activities		(159,100)	(35,153)
Proceeds from the issuance of:
Retirement of long-term debt		(1)	(11,405)
Changes in credit borrowings and commercial paper - net		111,012	(20,404)
Dividends paid:
Common stock		0	(20,000)
Other		(26)	(28)
Net cash flow provided by (used in) financing activities		110,985	(51,837)
Net decrease in cash and cash equivalents		25,041	(47,271)
Cash and cash equivalents at beginning of period		230,661	223,179
Cash and cash equivalents at end of period		255,702	175,908
Cash paid / (received) during the period for:
Interest - net of amount capitalized		8,593	26,208
Income taxes		$ (6,598)	$ 25,304
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $5.3 million and $3.2 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	Mar. 31, 2016	Dec. 31, 2015
Cash and cash equivalents:
Cash	$ 81,624	$ 63,497
Temporary cash investments	1,010,027	1,287,464
Total cash and cash equivalents	1,091,651	1,350,961
Accounts receivable:
Customer	559,584	608,491
Allowance for doubtful accounts	(41,377)	(39,895)
Other	170,771	178,364
Accrued unbilled revenues	304,446	321,940
Total accounts receivable	993,424	1,068,900
Deferred fuel costs	28,296	0
Fuel inventory - at average cost	226,898	217,810
Materials and supplies - at average cost	873,679	873,357
Deferred nuclear refueling outage costs	245,623	211,512
Prepayments and other	541,624	344,872
TOTAL	4,001,195	4,067,412
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	4,653	4,341
Decommissioning trust funds	5,451,729	5,349,953
Non-utility property - at cost (less accumulated depreciation)	221,431	219,999
Other	490,232	468,704
TOTAL	6,168,045	6,042,997
PROPERTY, PLANT, AND EQUIPMENT
Electric	46,578,818	44,467,159
Property under capital lease	610,590	952,465
Natural gas	396,687	392,032
Construction work in progress	1,426,671	1,456,735
Nuclear fuel	1,302,903	1,345,422
TOTAL PROPERTY, PLANT, AND EQUIPMENT	50,315,669	48,613,813
Less - accumulated depreciation and amortization	21,333,661	20,789,452
PROPERTY, PLANT, AND EQUIPMENT - NET	28,982,008	27,824,361
Regulatory assets:
Regulatory asset for income taxes - net	776,370	775,528
Other regulatory assets	4,647,907	4,704,796
Deferred fuel costs	238,951	238,902
Goodwill	377,172	377,172
Accumulated deferred income taxes	121,700	54,903
Other	620,534	561,610
TOTAL	6,782,634	6,712,911
TOTAL ASSETS	45,933,882	44,647,681
CURRENT LIABILITIES
Currently maturing long-term debt	796,732	214,374
Notes payable and commercial paper	766,079	494,348
Accounts payable	888,349	1,071,798
Customer deposits	423,564	419,407
Taxes Payable, Current	194,081	210,077
Interest accrued	167,030	194,565
Deferred fuel costs	361,897	235,986
Obligations under capital leases	2,762	2,709
Pension and other postretirement liabilities	62,789	62,513
Other	176,065	184,181
TOTAL	3,839,348	3,089,958
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	8,467,757	8,306,865
Accumulated deferred investment tax credits	231,610	234,300
Obligations under capital leases	26,290	27,001
Other regulatory liabilities	1,433,632	1,414,898
Decommissioning and asset retirement cost liabilities	4,808,315	4,790,187
Accumulated provisions	456,698	460,727
Pension and other postretirement liabilities	3,098,036	3,187,357
Long-term debt	13,500,140	13,111,556
Other	392,924	449,856
TOTAL	32,415,402	31,982,747
Subsidiaries' preferred stock without sinking fund	318,185	318,185
Common Shareholders' Equity:
Common stock	2,548	2,548
Paid-in capital	5,384,762	5,403,758
Retained earnings	9,472,040	9,393,913
Accumulated other comprehensive income	29,792	8,951
Less - treasury stock, at cost	5,528,195	5,552,379
TOTAL	9,360,947	9,256,791
TOTAL	9,360,947	9,256,791
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	45,933,882	44,647,681
Entergy Arkansas [Member]
Cash and cash equivalents:
Cash	20,416	9,066
Temporary cash investments	13,363	69
Total cash and cash equivalents	33,779	9,135
Securitization recovery trust account	7,617	4,204
Accounts receivable:
Customer	120,539	108,636
Allowance for doubtful accounts	(34,312)	(34,226)
Associated companies	37,130	32,987
Other	72,420	84,216
Accrued unbilled revenues	75,666	73,583
Total accounts receivable	271,443	265,196
Deferred fuel costs	28,296	0
Fuel inventory - at average cost	68,514	62,689
Materials and supplies - at average cost	173,554	169,919
Deferred nuclear refueling outage costs	52,195	67,834
Prepaid Taxes	29,081	30,291
Prepayments and other	11,611	15,145
TOTAL	676,090	624,413
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	785,503	771,313
Other	20,118	12,895
TOTAL	805,621	784,208
PROPERTY, PLANT, AND EQUIPMENT
Electric	10,021,925	9,536,802
Property under capital lease	812	844
Construction work in progress	358,522	388,075
Nuclear fuel	233,578	286,341
TOTAL PROPERTY, PLANT, AND EQUIPMENT	10,614,837	10,212,062
Less - accumulated depreciation and amortization	4,479,132	4,349,809
PROPERTY, PLANT, AND EQUIPMENT - NET	6,135,705	5,862,253
Regulatory assets:
Regulatory asset for income taxes - net	62,158	61,438
Other regulatory assets	1,332,161	1,333,773
Deferred fuel costs	66,749	66,700
Other	20,440	14,989
TOTAL	1,481,508	1,476,900
TOTAL ASSETS	9,098,924	8,747,774
CURRENT LIABILITIES
Currently maturing long-term debt	55,000	55,000
Short-term borrowings	0	11,690
Associated companies accounts payable	129,526	110,464
Other	136,648	177,758
Customer deposits	120,060	118,340
Interest accrued	25,111	19,883
Deferred fuel costs	0	8,853
Other	48,269	45,219
TOTAL	514,614	547,207
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	1,998,112	1,982,812
Accumulated deferred investment tax credits	36,206	36,506
Other regulatory liabilities	257,879	242,913
Decommissioning and asset retirement cost liabilities	885,448	872,346
Accumulated provisions	5,907	5,552
Pension and other postretirement liabilities	434,865	459,153
Long-term debt	2,722,649	2,574,839
Other	17,660	18,438
TOTAL	6,358,726	6,192,559
Subsidiaries' preferred stock without sinking fund	116,350	116,350
Common Shareholders' Equity:
Common stock	470	470
Paid-in capital	788,493	588,493
Retained earnings	1,320,271	1,302,695
TOTAL	2,109,234	1,891,658
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	9,098,924	8,747,774
Entergy Louisiana [Member]
Assets Held-in-trust, Current	196,568	0
Cash and cash equivalents:
Cash	11,957	348
Temporary cash investments	99,991	34,754
Total cash and cash equivalents	111,948	35,102
Accounts receivable:
Customer	166,483	179,051
Allowance for doubtful accounts	(5,781)	(4,209)
Associated companies	139,816	94,418
Other	60,825	56,793
Accrued unbilled revenues	141,227	143,079
Total accounts receivable	502,570	469,132
Fuel inventory - at average cost	50,583	48,045
Materials and supplies - at average cost	287,314	282,688
Deferred nuclear refueling outage costs	52,679	66,984
Prepayments and other	29,965	28,294
TOTAL	1,231,627	930,245
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	1,390,587	1,390,587
Decommissioning trust funds	1,065,165	1,042,293
Non-utility property - at cost (less accumulated depreciation)	207,963	206,293
Storm Reserve Escrow Account	290,665	290,422
Other	28,976	14,776
TOTAL	2,983,356	2,944,371
PROPERTY, PLANT, AND EQUIPMENT
Electric	18,729,802	17,629,077
Property under capital lease	0	341,514
Natural gas	162,314	159,252
Construction work in progress	390,215	420,874
Nuclear fuel	326,280	386,524
TOTAL PROPERTY, PLANT, AND EQUIPMENT	19,608,611	18,937,241
Less - accumulated depreciation and amortization	8,505,828	8,302,774
PROPERTY, PLANT, AND EQUIPMENT - NET	11,102,783	10,634,467
Regulatory assets:
Regulatory asset for income taxes - net	475,657	478,243
Other regulatory assets	1,190,427	1,217,874
Deferred fuel costs	168,122	168,122
Other	24,286	14,125
TOTAL	1,858,492	1,878,364
TOTAL ASSETS	17,176,258	16,387,447
CURRENT LIABILITIES
Currently maturing long-term debt	61,004	29,372
Short-term borrowings	77,450	60,356
Associated companies accounts payable	86,379	165,419
Other	193,603	276,280
Customer deposits	147,709	146,555
Taxes Payable, Current	20,698	125,142
Interest accrued	72,195	74,380
Deferred fuel costs	110,745	65,234
Other	77,000	79,982
TOTAL	846,783	1,022,720
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	2,668,395	2,506,956
Accumulated deferred investment tax credits	130,505	131,760
Regulatory liability for income taxes - net	0	2,473
Other regulatory liabilities	817,625	818,623
Decommissioning and asset retirement cost liabilities	1,041,300	1,027,862
Accumulated provisions	307,587	310,282
Pension and other postretirement liabilities	814,000	833,185
Long-term debt	5,559,230	4,806,790
Long-term payables of associated companies	671	1,073
Other	141,514	188,411
TOTAL	11,480,827	10,627,415
Common Shareholders' Equity:
Accumulated other comprehensive income	(56,675)	(56,412)
Members' Equity	4,905,323	4,793,724
TOTAL	4,848,648	4,737,312
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	17,176,258	16,387,447
Entergy Mississippi [Member]
Cash and cash equivalents:
Cash	1,277	1,426
Temporary cash investments	112,669	144,179
Total cash and cash equivalents	113,946	145,605
Accounts receivable:
Customer	50,148	56,685
Allowance for doubtful accounts	(499)	(718)
Associated companies	46,141	34,964
Other	5,009	8,276
Accrued unbilled revenues	40,429	47,284
Total accounts receivable	141,228	146,491
Fuel inventory - at average cost	54,517	51,273
Materials and supplies - at average cost	39,113	39,491
Prepayments and other	6,292	5,184
TOTAL	355,096	388,044
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,621	4,625
Escrow accounts	41,752	41,726
TOTAL	46,373	46,351
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,133,487	4,083,933
Property under capital lease	2,613	2,942
Construction work in progress	116,595	114,067
TOTAL PROPERTY, PLANT, AND EQUIPMENT	4,252,695	4,200,942
Less - accumulated depreciation and amortization	1,554,988	1,534,522
PROPERTY, PLANT, AND EQUIPMENT - NET	2,697,707	2,666,420
Regulatory assets:
Regulatory asset for income taxes - net	45,814	45,790
Other regulatory assets	327,906	328,681
Other	5,335	2,121
TOTAL	379,055	376,592
TOTAL ASSETS	3,478,231	3,477,407
CURRENT LIABILITIES
Currently maturing long-term debt	125,000	125,000
Associated companies accounts payable	31,226	38,496
Other	46,536	51,502
Customer deposits	82,493	81,583
Taxes Payable, Current	19,452	43,461
Interest accrued	18,798	20,831
Deferred fuel costs	148,104	107,754
Other	21,627	22,754
TOTAL	493,236	491,381
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	804,273	810,635
Accumulated deferred investment tax credits	4,605	4,645
Decommissioning and asset retirement cost liabilities	8,367	8,252
Accumulated provisions	46,046	48,062
Pension and other postretirement liabilities	114,199	120,217
Long-term debt	920,430	920,085
Other	8,233	11,699
TOTAL	1,906,153	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	829,825	813,414
TOTAL	1,028,461	1,012,050
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	3,478,231	3,477,407
Entergy New Orleans [Member]
Cash and cash equivalents:
Cash	652	1,068
Temporary cash investments	5,316	87,808
Total cash and cash equivalents	5,968	88,876
Securitization recovery trust account	7,366	4,620
Accounts receivable:
Customer	39,245	34,627
Allowance for doubtful accounts	(289)	(268)
Associated companies	9,063	23,248
Other	6,099	3,753
Accrued unbilled revenues	15,328	17,799
Total accounts receivable	69,446	79,159
Fuel inventory - at average cost	394	1,912
Materials and supplies - at average cost	15,257	13,244
Prepayments and other	17,932	10,263
TOTAL	116,363	198,074
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	1,016	1,016
Storm Reserve Escrow Account	81,102	81,002
Other	7,119	0
TOTAL	89,237	82,018
PROPERTY, PLANT, AND EQUIPMENT
Electric	1,390,403	1,051,239
Natural gas	234,374	232,780
Construction work in progress	18,582	29,027
TOTAL PROPERTY, PLANT, AND EQUIPMENT	1,643,359	1,313,046
Less - accumulated depreciation and amortization	740,029	648,081
PROPERTY, PLANT, AND EQUIPMENT - NET	903,330	664,965
Regulatory assets:
Other regulatory assets	259,052	265,322
Deferred fuel costs	4,080	4,080
Other	2,089	685
TOTAL	265,221	270,087
TOTAL ASSETS	1,374,151	1,215,144
CURRENT LIABILITIES
Current payable due Entergy Louisiana	4,973	4,973
Associated companies accounts payable	35,163	37,467
Other	22,583	21,471
Customer deposits	28,497	28,392
Taxes Payable, Current	14,187	0
Interest accrued	4,330	4,909
Deferred fuel costs	23,733	29,021
Other	9,525	6,216
TOTAL	142,991	132,449
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	203,650	214,061
Accumulated deferred investment tax credits	722	753
Regulatory liability for income taxes - net	11,841	13,199
Decommissioning and asset retirement cost liabilities	2,733	2,687
Accumulated provisions	83,655	84,187
Pension and other postretirement liabilities	39,507	43,609
Long-term debt	424,392	317,380
Gas system rebuild insurance proceeds	10,269	12,788
Long-term payable due to Entergy Louisiana	20,527	20,527
Other	5,376	3,692
TOTAL	802,672	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	203,420	192,494
TOTAL	408,708	350,032
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	1,374,151	1,215,144
Entergy Texas [Member]
Cash and cash equivalents:
Cash	1,550	2,153
Temporary cash investments	64,783	29
Total cash and cash equivalents	66,333	2,182
Securitization recovery trust account	27,897	38,161
Accounts receivable:
Customer	53,133	61,870
Allowance for doubtful accounts	(495)	(474)
Associated companies	66,773	42,279
Other	10,537	11,054
Accrued unbilled revenues	31,796	40,195
Total accounts receivable	161,744	154,924
Fuel inventory - at average cost	44,082	46,942
Materials and supplies - at average cost	35,415	34,994
Prepayments and other	11,693	17,975
TOTAL	347,164	295,178
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	613	620
Non-utility property - at cost (less accumulated depreciation)	376	376
Other	20,426	20,186
TOTAL	21,415	21,182
PROPERTY, PLANT, AND EQUIPMENT
Electric	3,947,837	3,923,100
Construction work in progress	239,695	210,964
TOTAL PROPERTY, PLANT, AND EQUIPMENT	4,187,532	4,134,064
Less - accumulated depreciation and amortization	1,479,969	1,477,529
PROPERTY, PLANT, AND EQUIPMENT - NET	2,707,563	2,656,535
Regulatory assets:
Regulatory asset for income taxes - net	107,650	107,499
Other regulatory assets	788,401	812,862
Other	8,084	5,326
TOTAL	904,135	925,687
TOTAL ASSETS	3,980,277	3,898,582
CURRENT LIABILITIES
Associated companies accounts payable	74,610	106,065
Other	63,654	87,421
Customer deposits	44,806	44,537
Taxes Payable, Current	24,204	5,333
Interest accrued	19,228	29,206
Deferred fuel costs	79,316	25,124
Other	6,179	10,363
TOTAL	311,997	308,049
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	977,049	1,006,834
Accumulated deferred investment tax credits	13,609	13,835
Other regulatory liabilities	6,446	6,396
Decommissioning and asset retirement cost liabilities	6,209	6,124
Accumulated provisions	9,981	9,319
Pension and other postretirement liabilities	71,023	77,517
Long-term debt	1,552,741	1,451,967
Other	55,204	57,085
TOTAL	2,692,262	2,629,077
Common Shareholders' Equity:
Common stock	49,452	49,452
Paid-in capital	481,994	481,994
Retained earnings	444,572	430,010
TOTAL	976,018	961,456
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	3,980,277	3,898,582
System Energy [Member]
Cash and cash equivalents:
Cash	698	8,681
Temporary cash investments	255,004	221,980
Total cash and cash equivalents	255,702	230,661
Accounts receivable:
Associated companies	76,847	93,724
Other	7,602	4,574
Total accounts receivable	84,449	98,298
Materials and supplies - at average cost	78,850	87,366
Deferred nuclear refueling outage costs	39,352	5,605
Prepaid Taxes	47,944	9,327
Prepayments and other	6,849	1,955
TOTAL	513,146	433,212
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	719,769	701,460
TOTAL	719,769	701,460
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,313,474	4,253,949
Property under capital lease	575,027	575,027
Construction work in progress	74,726	92,546
Nuclear fuel	285,426	183,706
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,248,653	5,105,228
Less - accumulated depreciation and amortization	2,992,700	2,961,842
PROPERTY, PLANT, AND EQUIPMENT - NET	2,255,953	2,143,386
Regulatory assets:
Regulatory asset for income taxes - net	96,933	98,230
Other regulatory assets	357,446	347,830
Other	4,881	4,757
TOTAL	459,260	450,817
TOTAL ASSETS	3,948,128	3,728,875
CURRENT LIABILITIES
Currently maturing long-term debt	50,002	2
Short-term borrowings	111,012	0
Associated companies accounts payable	3,663	7,391
Other	58,048	34,010
Interest accrued	15,020	14,183
Other	1,940	1,926
TOTAL	239,685	57,512
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	1,065,590	1,019,075
Accumulated deferred investment tax credits	44,646	45,451
Other regulatory liabilities	344,950	337,424
Decommissioning and asset retirement cost liabilities	815,792	803,405
Pension and other postretirement liabilities	107,688	112,264
Long-term debt	522,740	572,665
TOTAL	2,901,406	2,890,284
Common Shareholders' Equity:
Common stock	719,350	719,350
Retained earnings	87,687	61,729
TOTAL	807,037	781,079
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$ 3,948,128	$ 3,728,875

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Securitization property	$ 689,885	$ 714,044
Securitization bonds	$ 751,595	$ 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	76,031,187	76,363,763
Entergy Arkansas [Member]
Securitization property	$ 51,360	$ 54,450
Securitization bonds	$ 61,326	$ 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	$ 109,773	$ 114,701
Securitization bonds	$ 120,615	$ 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	$ 89,585	$ 91,599
Securitization bonds	$ 95,930	$ 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	$ 439,167	$ 453,317
Securitization bonds	$ 473,724	$ 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]		Common Stock [Member]	Treasury Stock [Member]	Paid In Capital [Member]	Retained Earnings [Member]		Accumulated Other Comprehensive Income [Member]	Entergy Arkansas [Member]	Entergy Arkansas [Member]Common Stock [Member]	Entergy Arkansas [Member]Paid In Capital [Member]	Entergy Arkansas [Member]Retained Earnings [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]Common Stock [Member]	Entergy Mississippi [Member]Capital Stock Expense and Other [Member]	Entergy Mississippi [Member]Retained Earnings [Member]	Entergy New Orleans [Member]	Entergy New Orleans [Member]Common Stock [Member]	Entergy New Orleans [Member]Paid In Capital [Member]	Entergy New Orleans [Member]Retained Earnings [Member]	Entergy Texas [Member]	Entergy Texas [Member]Common Stock [Member]	Entergy Texas [Member]Paid In Capital [Member]	Entergy Texas [Member]Retained Earnings [Member]	System Energy [Member]	System Energy [Member]Common Stock [Member]	System Energy [Member]Retained Earnings [Member]
Beginning Balance at Dec. 31, 2014	$ 10,101,725		$ 94,000		$ 2,548	$ (5,497,526)	$ 5,375,353	$ 10,169,657		$ (42,307)	$ 1,824,237	$ 470	$ 588,471	$ 1,235,296	$ 4,336,987	$ 100,000	$ 4,316,210	$ (79,223)	$ 962,170	$ 199,326	$ (690)	$ 763,534	$ 228,025	$ 33,744	$ 36,294	$ 157,987	$ 891,831	$ 49,452	$ 481,994	$ 360,385	$ 870,511	$ 789,350	$ 81,161
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Consolidated net income	302,929	[1]	4,879	[1]	0	0	0	298,050	[1]	0	17,865	0	0	17,865	126,109	0	126,109	0	24,935	0	0	24,935	11,292	0	0	11,292	16,591	0	0	16,591	25,533	0	25,533
Net income attributable to Entergy Louisiana																							(238)	0	0	(238)
Other comprehensive income (loss)	(17,430)		0		0	0	0	0		(17,430)					380	0	0	380
Payments for Repurchase of Common Stock	(25,078)		0		0	(25,078)	0	0		0
Common stock issuances related to stock plans	19,969		0		0	43,632	(23,663)	0		0
Common stock dividends declared	(149,257)		0		0	0	0	(149,257)		0													(7,250)	0	0	(7,250)					(20,000)	0	(20,000)
Proceeds from Contributions from Parent											0												0
Preferred dividend requirements of subsidiaries	(4,879)	[1]	(4,879)	[1]	0	0	0	0		0	(1,718)	0	0	(1,718)	(1,944)	0	(1,944)	0	(707)	0	0	(707)	(241)	0	0	(241)
Other															(8)	0	(8)	0
Ending Balance at Mar. 31, 2015	10,227,979		94,000		2,548	(5,478,972)	5,351,690	10,318,450		(59,737)	1,840,384	470	588,471	1,251,443	4,461,524	100,000	4,440,367	(78,843)	986,398	199,326	(690)	787,762	231,588	33,744	36,294	161,550	908,422	49,452	481,994	376,976	876,044	789,350	86,694
Beginning Balance at Dec. 31, 2015	9,256,791		0		2,548	(5,552,379)	5,403,758	9,393,913		8,951	1,891,658	470	588,493	1,302,695	4,737,312	0	4,793,724	(56,412)	1,012,050	199,326	(690)	813,414	350,032	33,744	123,794	192,494	961,456	49,452	481,994	430,010	781,079	719,350	61,729
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Consolidated net income	235,242	[1]	5,276	[1]	0	0	0	229,966	[1]	0	19,294	0	0	19,294	111,606	0	111,606	0	17,118	0	0	17,118	11,167	0	0	11,167	14,562	0	0	14,562	25,958	0	25,958
Other comprehensive income (loss)	20,841		0		0	0	0	0		20,841					(263)	0	0	(263)
Payments for Repurchase of Common Stock	0
Common stock issuances related to stock plans	5,188		0		0	24,184	(18,996)	0		0
Common stock dividends declared	(151,839)		0		0	0	0	(151,839)		0
Proceeds from Contributions from Parent											200,000	0	200,000	0									47,750	0	47,750	0
Preferred dividend requirements of subsidiaries	(5,276)	[1]	(5,276)	[1]	0	0	0	0		0	(1,718)	0	0	(1,718)					(707)	0	0	(707)	241	0	0	(241)
Other															(7)	0	(7)	0
Ending Balance at Mar. 31, 2016	$ 9,360,947		$ 0		$ 2,548	$ (5,528,195)	$ 5,384,762	$ 9,472,040		$ 29,792	$ 2,109,234	$ 470	$ 788,493	$ 1,320,271	$ 4,848,648	$ 0	$ 4,905,323	$ (56,675)	$ 1,028,461	$ 199,326	$ (690)	$ 829,825	$ 408,708	$ 33,744	$ 171,544	$ 203,420	$ 976,018	$ 49,452	$ 481,994	$ 444,572	$ 807,037	$ 719,350	$ 87,687
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $5.3 million and $3.2 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	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Statement of Stockholders' Equity [Abstract]
Preferred dividends on subsidiaries' preferred stock	$ 5.3	$ 3.2

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Net income	[1]	$ 235,242	$ 302,929
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss)		(9,506)	(29,330)
Pension and other postretirement liabilities		7,562	8,448
Net unrealized investment gains		23,069	4,003
Foreign currency translation		(284)	(551)
Other comprehensive income (loss)		20,841	(17,430)
Total comprehensive income		256,083	285,499
Preferred dividend requirements of subsidiaries	[1]	5,276	4,879
Comprehensive Income Attributable to Entergy Corporation		250,807	280,620
Entergy Louisiana [Member]
Net income		111,606	126,109
Other comprehensive income (loss)
Pension and other postretirement liabilities		(263)	380
Other comprehensive income (loss)		(263)	380
Total comprehensive income		$ 111,343	126,489
Preferred dividend requirements of subsidiaries			$ 1,944
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $5.3 million and $3.2 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
	Mar. 31, 2016	Mar. 31, 2015
Cash flow hedges net unrealized gain (loss), tax expense (benefit)	$ (5,201)	$ (15,898)
Pension and other postretirement liabilities, tax expense	258	3,175
Net unrealized investment gains, tax expense	18,358	3,666
Foreign currency translation, tax expense	(153)	(296)
Entergy Louisiana [Member]
Pension and other postretirement liabilities, tax expense	$ (115)	$ 288

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 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 $19.6 million was incurred in the first quarter 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. 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 $5 million was incurred in the first quarter 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. 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, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation at Entergy Louisiana, Entergy New Orleans, 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 $19.6 million was incurred in the first quarter 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. 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 $5 million was incurred in the first quarter 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. 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, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation at Entergy Louisiana, Entergy New Orleans, 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 $19.6 million was incurred in the first quarter 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. 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 $5 million was incurred in the first quarter 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. 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, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation at Entergy Louisiana, Entergy New Orleans, 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 $19.6 million was incurred in the first quarter 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. 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 $5 million was incurred in the first quarter 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. 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, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation at Entergy Louisiana, Entergy New Orleans, 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 $19.6 million was incurred in the first quarter 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. 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 $5 million was incurred in the first quarter 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. 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, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation at Entergy Louisiana, Entergy New Orleans, 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 $19.6 million was incurred in the first quarter 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. 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 $5 million was incurred in the first quarter 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. 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, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation at Entergy Louisiana, Entergy New Orleans, 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 $19.6 million was incurred in the first quarter 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. 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 $5 million was incurred in the first quarter 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. 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, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation at Entergy Louisiana, Entergy New Orleans, and Entergy Texas.

Rate And Regulatory Matters

Rate And Regulatory Matters	3 Months Ended
	Mar. 31, 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 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. 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. A procedural schedule has not been established for this proceeding, and discovery from intervenors 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. 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. 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. Entergy Texas requested that the refund be made to most customers over a four-month period beginning June 2016. 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, 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 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. Entergy Arkansas plans to make its first formula rate plan filing in July 2016 for rates effective with the first billing cycle of January 2017. Filings with the LPSC Retail Rates - Electric 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 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 has 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. 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 , subject to closing adjustments, and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. 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. Discovery regarding these issues is pending, but a procedural schedule has not been established for addressing the outstanding issues. 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 terms of the gas rate stabilization plan for an additional three-year term. A procedural schedule has not been established. 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 shows a $32.6 million rate increase is 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. The filing is currently subject to MPSC review. In April 2016 the Mississippi Public Utilities Staff filed a letter disputing the formula rate plan evaluation report subject to its continued review of the submittal. A final order is expected in second quarter 2016, with the resulting rates effective mid-year 2016. Pursuant to the terms of the formula rate plan, Entergy Mississippi also submitted an informational look-back filing for 2015 that showed Entergy Mississippi’s 2015 earned return was within the formula rate plan bandwidth. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6 as well as the revenue requirement associated with the acquisition of Power Block 1 of Union Power Station. In March 2016, Entergy New Orleans acquired Power Block 1 of Union Power Station for approximately $237 million , subject to closing adjustments, and initiated recovery of these costs with March 2016 bills. Filings with the PUCT 2011 Rate Case See the Form 10-K for discussion of Entergy Texas’s 2011 rate case. As discussed in the Form 10-K, several parties, including Entergy Texas, appealed various aspects of the PUCT’s order to the Travis County District Court. In October 2014 the Travis County District Court issued an order upholding the PUCT’s decision except as to the line-loss factor issue referenced in the Form 10-K, which was found in favor of Entergy Texas. In November 2014, Entergy Texas and other parties, including the PUCT, appealed the Travis County District Court decision to the Third Court of Appeals. Oral argument before the court panel was held in September 2015. In April 2016 the Third Court of Appeals issued its opinion affirming the District Court’s decision on all points. Entergy Texas plans to petition the Texas Supreme Court to hear its appeal of the Third Court’s ruling. Other Filings In September 2015, Entergy Texas filed for a transmission cost recovery factor rider requesting a $13 million increase, incremental to base rates. Testimony was filed in November 2015, with the PUCT staff and other parties proposing various disallowances involving, among other things, MISO charges, vegetation management costs, and bad debt expenses that would reduce the requested increase by approximately $2 million . In addition to those recommended disallowances, a number of parties recommended that Entergy Texas’s request be reduced by an additional $3.4 million to account for load growth since base rates were last set. A hearing on the merits was held in December 2015. In February 2016 a State Office of Administrative Hearings ALJ issued a proposal for decision recommending that the PUCT disallow approximately $2 million from Entergy Texas’s $13 million request, but recommending that the PUCT not accept the load growth offset. In May 2016 the PUCT deferred final consideration of Entergy Texas’s TCRF application and opened the record to consider additional evidence to be provided by Entergy Texas and potentially other parties regarding the rate-making treatment of spare transmission-level transformers that are transferred among the Utility operating companies. It is not known when the PUCT will take up the merits of this matter, but Entergy Texas was granted interim rates as of April 14, 2016 whenever a final order is issued setting those rates. System Agreement Cost Equalization Proceedings Rough Production Cost Equalization Rates 2015 Rate Filing Based on Calendar Year 2014 Production Costs In May 2015, Entergy filed with the FERC the 2015 rates in accordance with the FERC’s orders in the System Agreement proceeding. The filing shows that no payments and receipts are required in 2015 to implement the FERC’s remedy based on calendar year 2014 production costs. Several parties intervened in the proceeding and the LPSC and City Council intervened and filed comments. In October 2015 the FERC accepted the 2015 rates for filing, suspended them for a nominal period, to become effective June 1, 2015, as requested, subject to refund, and set them for hearing and settlement judge procedures. In March 2016, Entergy Services filed a settlement at the FERC resolving the 2015 rate filing. In the settlement, the parties did not dispute the 2015 rates as calculated with no payments or receipts. Pursuant to the settlement, the 2015 rates are subject to a recalculation and compliance filing upon resolution of other ongoing bandwidth-related proceedings. Interruptible Load Proceedings See the Form 10-K for a discussion of the interruptible load proceeding. In April 2016 the FERC issued an order on remand that addressed the December 2014 decision by the D.C. Circuit in the interruptible load proceeding. The order on remand affirmed the FERC’s denial of refunds for the 15-month refund effective period. The FERC explained and clarified its policies regarding refunds and concluded that the evidence in the record demonstrated that the relevant equitable factors favored not requiring refunds in this case. The FERC also noted that, under Section 206(c) of the Federal Power Act, in a Section 206 proceeding involving two or more electric utility companies of a registered holding company system, the FERC may order refunds only if it determines the refunds would not cause the registered holding company to experience any reduction in revenues resulting from an inability of an electric utility company in the system to recover the resulting increase in costs. The FERC stated it was not able to find that the Entergy system would not experience a reduction in revenues if refunds were awarded in this proceeding, which further supported the denial of refunds. Entergy Arkansas Opportunity Sales Proceedings See the Form 10-K for a discussion of the proceeding initiated at the FERC by the LPSC in June 2009 in which the LPSC initially requested that the FERC determine that certain of Entergy Arkansas’s sales of electric energy to third parties: (a) violated the provisions of the System Agreement that allocate the energy generated by Entergy System resources, (b) imprudently denied the Entergy System and its ultimate consumers the benefits of low-cost Entergy System generating capacity, and (c) violated the provision of the System Agreement that prohibits sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. In April 2016 the FERC issued orders addressing the requests for rehearing filed in July 2012 and the ALJ’s August 2013 initial decision. The first order denies Entergy’s request for rehearing and affirms FERC’s earlier rulings that Entergy’s original methodology for allocating energy costs to the opportunity sales was incorrect and, as a result, Entergy Arkansas must make payments to the other Utility operating companies to put them in the same position that they would have been in absent the incorrect allocation. The FERC clarified that interest should be included with the payments. The second order affirmed in part, and reversed in part, the rulings in the ALJ’s initial decision regarding the methodology that should be used to calculate the payments Entergy Arkansas is to make to the other Utility operating companies. The FERC affirmed the ALJ’s ruling that a full re-run of intra-system bills should be performed, but required that methodology be modified so that the sales have the same priority for purposes of energy allocation as joint account sales. The FERC reversed the ALJ’s decision that any payments by Entergy Arkansas should be reduced by 20% . The FERC also reversed the ALJ’s decision that adjustments to other System Agreement service schedules and excess bandwidth payments should not be taken into account when calculating the payments to be made by Entergy Arkansas. The FERC held that such adjustments and excess bandwidth payments should be taken into account, but ordered further proceedings before an ALJ to address whether a cap on any reduction due to bandwidth payments was necessary and to implement the other adjustments to the calculation methodology. The effect of the FERC’s decisions, if upheld, is that Entergy Arkansas will make payments to some or all of the other Utility operating companies. As part of the further proceedings required by the FERC, Entergy will re-run intra-system bills for a ten-year period (2000-2009) to quantify the effects of the FERC's rulings. The ALJ will issue an initial decision and FERC will issue an order reviewing that decision. No payments will be made or received by the Utility operating companies until the FERC issues an order reviewing that initial decision and Entergy submits a subsequent filing to comply with that order. Because further proceedings are required, the amount and recipients of payments by Entergy Arkansas are unknown at this time. Based on testimony previously submitted in the case, however, in the first quarter 2016 Entergy Arkansas recorded a liability of $87 million for its estimated increased costs and payment to the other Utility operating companies, including interest. This estimate is subject to change depending on how the FERC resolves the issues that are still outstanding in the case. Entergy Arkansas’s increased costs will be attributed to Entergy Arkansas’s retail and wholesale businesses, and it is not probable that Entergy Arkansas will recover the wholesale portion. Therefore Entergy Arkansas recorded a regulatory asset of approximately $75 million , which represents its estimate of the retail portion of the costs.
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 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. 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. A procedural schedule has not been established for this proceeding, and discovery from intervenors 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. 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. 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. Entergy Texas requested that the refund be made to most customers over a four-month period beginning June 2016. 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, 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 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. Entergy Arkansas plans to make its first formula rate plan filing in July 2016 for rates effective with the first billing cycle of January 2017. Filings with the LPSC Retail Rates - Electric 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 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 has 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. 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 , subject to closing adjustments, and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. 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. Discovery regarding these issues is pending, but a procedural schedule has not been established for addressing the outstanding issues. 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 terms of the gas rate stabilization plan for an additional three-year term. A procedural schedule has not been established. 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 shows a $32.6 million rate increase is 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. The filing is currently subject to MPSC review. In April 2016 the Mississippi Public Utilities Staff filed a letter disputing the formula rate plan evaluation report subject to its continued review of the submittal. A final order is expected in second quarter 2016, with the resulting rates effective mid-year 2016. Pursuant to the terms of the formula rate plan, Entergy Mississippi also submitted an informational look-back filing for 2015 that showed Entergy Mississippi’s 2015 earned return was within the formula rate plan bandwidth. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6 as well as the revenue requirement associated with the acquisition of Power Block 1 of Union Power Station. In March 2016, Entergy New Orleans acquired Power Block 1 of Union Power Station for approximately $237 million , subject to closing adjustments, and initiated recovery of these costs with March 2016 bills. Filings with the PUCT 2011 Rate Case See the Form 10-K for discussion of Entergy Texas’s 2011 rate case. As discussed in the Form 10-K, several parties, including Entergy Texas, appealed various aspects of the PUCT’s order to the Travis County District Court. In October 2014 the Travis County District Court issued an order upholding the PUCT’s decision except as to the line-loss factor issue referenced in the Form 10-K, which was found in favor of Entergy Texas. In November 2014, Entergy Texas and other parties, including the PUCT, appealed the Travis County District Court decision to the Third Court of Appeals. Oral argument before the court panel was held in September 2015. In April 2016 the Third Court of Appeals issued its opinion affirming the District Court’s decision on all points. Entergy Texas plans to petition the Texas Supreme Court to hear its appeal of the Third Court’s ruling. Other Filings In September 2015, Entergy Texas filed for a transmission cost recovery factor rider requesting a $13 million increase, incremental to base rates. Testimony was filed in November 2015, with the PUCT staff and other parties proposing various disallowances involving, among other things, MISO charges, vegetation management costs, and bad debt expenses that would reduce the requested increase by approximately $2 million . In addition to those recommended disallowances, a number of parties recommended that Entergy Texas’s request be reduced by an additional $3.4 million to account for load growth since base rates were last set. A hearing on the merits was held in December 2015. In February 2016 a State Office of Administrative Hearings ALJ issued a proposal for decision recommending that the PUCT disallow approximately $2 million from Entergy Texas’s $13 million request, but recommending that the PUCT not accept the load growth offset. In May 2016 the PUCT deferred final consideration of Entergy Texas’s TCRF application and opened the record to consider additional evidence to be provided by Entergy Texas and potentially other parties regarding the rate-making treatment of spare transmission-level transformers that are transferred among the Utility operating companies. It is not known when the PUCT will take up the merits of this matter, but Entergy Texas was granted interim rates as of April 14, 2016 whenever a final order is issued setting those rates. System Agreement Cost Equalization Proceedings Rough Production Cost Equalization Rates 2015 Rate Filing Based on Calendar Year 2014 Production Costs In May 2015, Entergy filed with the FERC the 2015 rates in accordance with the FERC’s orders in the System Agreement proceeding. The filing shows that no payments and receipts are required in 2015 to implement the FERC’s remedy based on calendar year 2014 production costs. Several parties intervened in the proceeding and the LPSC and City Council intervened and filed comments. In October 2015 the FERC accepted the 2015 rates for filing, suspended them for a nominal period, to become effective June 1, 2015, as requested, subject to refund, and set them for hearing and settlement judge procedures. In March 2016, Entergy Services filed a settlement at the FERC resolving the 2015 rate filing. In the settlement, the parties did not dispute the 2015 rates as calculated with no payments or receipts. Pursuant to the settlement, the 2015 rates are subject to a recalculation and compliance filing upon resolution of other ongoing bandwidth-related proceedings. Interruptible Load Proceedings See the Form 10-K for a discussion of the interruptible load proceeding. In April 2016 the FERC issued an order on remand that addressed the December 2014 decision by the D.C. Circuit in the interruptible load proceeding. The order on remand affirmed the FERC’s denial of refunds for the 15-month refund effective period. The FERC explained and clarified its policies regarding refunds and concluded that the evidence in the record demonstrated that the relevant equitable factors favored not requiring refunds in this case. The FERC also noted that, under Section 206(c) of the Federal Power Act, in a Section 206 proceeding involving two or more electric utility companies of a registered holding company system, the FERC may order refunds only if it determines the refunds would not cause the registered holding company to experience any reduction in revenues resulting from an inability of an electric utility company in the system to recover the resulting increase in costs. The FERC stated it was not able to find that the Entergy system would not experience a reduction in revenues if refunds were awarded in this proceeding, which further supported the denial of refunds. Entergy Arkansas Opportunity Sales Proceedings See the Form 10-K for a discussion of the proceeding initiated at the FERC by the LPSC in June 2009 in which the LPSC initially requested that the FERC determine that certain of Entergy Arkansas’s sales of electric energy to third parties: (a) violated the provisions of the System Agreement that allocate the energy generated by Entergy System resources, (b) imprudently denied the Entergy System and its ultimate consumers the benefits of low-cost Entergy System generating capacity, and (c) violated the provision of the System Agreement that prohibits sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. In April 2016 the FERC issued orders addressing the requests for rehearing filed in July 2012 and the ALJ’s August 2013 initial decision. The first order denies Entergy’s request for rehearing and affirms FERC’s earlier rulings that Entergy’s original methodology for allocating energy costs to the opportunity sales was incorrect and, as a result, Entergy Arkansas must make payments to the other Utility operating companies to put them in the same position that they would have been in absent the incorrect allocation. The FERC clarified that interest should be included with the payments. The second order affirmed in part, and reversed in part, the rulings in the ALJ’s initial decision regarding the methodology that should be used to calculate the payments Entergy Arkansas is to make to the other Utility operating companies. The FERC affirmed the ALJ’s ruling that a full re-run of intra-system bills should be performed, but required that methodology be modified so that the sales have the same priority for purposes of energy allocation as joint account sales. The FERC reversed the ALJ’s decision that any payments by Entergy Arkansas should be reduced by 20% . The FERC also reversed the ALJ’s decision that adjustments to other System Agreement service schedules and excess bandwidth payments should not be taken into account when calculating the payments to be made by Entergy Arkansas. The FERC held that such adjustments and excess bandwidth payments should be taken into account, but ordered further proceedings before an ALJ to address whether a cap on any reduction due to bandwidth payments was necessary and to implement the other adjustments to the calculation methodology. The effect of the FERC’s decisions, if upheld, is that Entergy Arkansas will make payments to some or all of the other Utility operating companies. As part of the further proceedings required by the FERC, Entergy will re-run intra-system bills for a ten-year period (2000-2009) to quantify the effects of the FERC's rulings. The ALJ will issue an initial decision and FERC will issue an order reviewing that decision. No payments will be made or received by the Utility operating companies until the FERC issues an order reviewing that initial decision and Entergy submits a subsequent filing to comply with that order. Because further proceedings are required, the amount and recipients of payments by Entergy Arkansas are unknown at this time. Based on testimony previously submitted in the case, however, in the first quarter 2016 Entergy Arkansas recorded a liability of $87 million for its estimated increased costs and payment to the other Utility operating companies, including interest. This estimate is subject to change depending on how the FERC resolves the issues that are still outstanding in the case. Entergy Arkansas’s increased costs will be attributed to Entergy Arkansas’s retail and wholesale businesses, and it is not probable that Entergy Arkansas will recover the wholesale portion. Therefore Entergy Arkansas recorded a regulatory asset of approximately $75 million , which represents its estimate of the retail portion of the costs.
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 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. 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. A procedural schedule has not been established for this proceeding, and discovery from intervenors 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. 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. 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. Entergy Texas requested that the refund be made to most customers over a four-month period beginning June 2016. 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, 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 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. Entergy Arkansas plans to make its first formula rate plan filing in July 2016 for rates effective with the first billing cycle of January 2017. Filings with the LPSC Retail Rates - Electric 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 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 has 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. 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 , subject to closing adjustments, and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. 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. Discovery regarding these issues is pending, but a procedural schedule has not been established for addressing the outstanding issues. 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 terms of the gas rate stabilization plan for an additional three-year term. A procedural schedule has not been established. 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 shows a $32.6 million rate increase is 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. The filing is currently subject to MPSC review. In April 2016 the Mississippi Public Utilities Staff filed a letter disputing the formula rate plan evaluation report subject to its continued review of the submittal. A final order is expected in second quarter 2016, with the resulting rates effective mid-year 2016. Pursuant to the terms of the formula rate plan, Entergy Mississippi also submitted an informational look-back filing for 2015 that showed Entergy Mississippi’s 2015 earned return was within the formula rate plan bandwidth. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6 as well as the revenue requirement associated with the acquisition of Power Block 1 of Union Power Station. In March 2016, Entergy New Orleans acquired Power Block 1 of Union Power Station for approximately $237 million , subject to closing adjustments, and initiated recovery of these costs with March 2016 bills. Filings with the PUCT 2011 Rate Case See the Form 10-K for discussion of Entergy Texas’s 2011 rate case. As discussed in the Form 10-K, several parties, including Entergy Texas, appealed various aspects of the PUCT’s order to the Travis County District Court. In October 2014 the Travis County District Court issued an order upholding the PUCT’s decision except as to the line-loss factor issue referenced in the Form 10-K, which was found in favor of Entergy Texas. In November 2014, Entergy Texas and other parties, including the PUCT, appealed the Travis County District Court decision to the Third Court of Appeals. Oral argument before the court panel was held in September 2015. In April 2016 the Third Court of Appeals issued its opinion affirming the District Court’s decision on all points. Entergy Texas plans to petition the Texas Supreme Court to hear its appeal of the Third Court’s ruling. Other Filings In September 2015, Entergy Texas filed for a transmission cost recovery factor rider requesting a $13 million increase, incremental to base rates. Testimony was filed in November 2015, with the PUCT staff and other parties proposing various disallowances involving, among other things, MISO charges, vegetation management costs, and bad debt expenses that would reduce the requested increase by approximately $2 million . In addition to those recommended disallowances, a number of parties recommended that Entergy Texas’s request be reduced by an additional $3.4 million to account for load growth since base rates were last set. A hearing on the merits was held in December 2015. In February 2016 a State Office of Administrative Hearings ALJ issued a proposal for decision recommending that the PUCT disallow approximately $2 million from Entergy Texas’s $13 million request, but recommending that the PUCT not accept the load growth offset. In May 2016 the PUCT deferred final consideration of Entergy Texas’s TCRF application and opened the record to consider additional evidence to be provided by Entergy Texas and potentially other parties regarding the rate-making treatment of spare transmission-level transformers that are transferred among the Utility operating companies. It is not known when the PUCT will take up the merits of this matter, but Entergy Texas was granted interim rates as of April 14, 2016 whenever a final order is issued setting those rates. System Agreement Cost Equalization Proceedings Rough Production Cost Equalization Rates 2015 Rate Filing Based on Calendar Year 2014 Production Costs In May 2015, Entergy filed with the FERC the 2015 rates in accordance with the FERC’s orders in the System Agreement proceeding. The filing shows that no payments and receipts are required in 2015 to implement the FERC’s remedy based on calendar year 2014 production costs. Several parties intervened in the proceeding and the LPSC and City Council intervened and filed comments. In October 2015 the FERC accepted the 2015 rates for filing, suspended them for a nominal period, to become effective June 1, 2015, as requested, subject to refund, and set them for hearing and settlement judge procedures. In March 2016, Entergy Services filed a settlement at the FERC resolving the 2015 rate filing. In the settlement, the parties did not dispute the 2015 rates as calculated with no payments or receipts. Pursuant to the settlement, the 2015 rates are subject to a recalculation and compliance filing upon resolution of other ongoing bandwidth-related proceedings. Interruptible Load Proceedings See the Form 10-K for a discussion of the interruptible load proceeding. In April 2016 the FERC issued an order on remand that addressed the December 2014 decision by the D.C. Circuit in the interruptible load proceeding. The order on remand affirmed the FERC’s denial of refunds for the 15-month refund effective period. The FERC explained and clarified its policies regarding refunds and concluded that the evidence in the record demonstrated that the relevant equitable factors favored not requiring refunds in this case. The FERC also noted that, under Section 206(c) of the Federal Power Act, in a Section 206 proceeding involving two or more electric utility companies of a registered holding company system, the FERC may order refunds only if it determines the refunds would not cause the registered holding company to experience any reduction in revenues resulting from an inability of an electric utility company in the system to recover the resulting increase in costs. The FERC stated it was not able to find that the Entergy system would not experience a reduction in revenues if refunds were awarded in this proceeding, which further supported the denial of refunds. Entergy Arkansas Opportunity Sales Proceedings See the Form 10-K for a discussion of the proceeding initiated at the FERC by the LPSC in June 2009 in which the LPSC initially requested that the FERC determine that certain of Entergy Arkansas’s sales of electric energy to third parties: (a) violated the provisions of the System Agreement that allocate the energy generated by Entergy System resources, (b) imprudently denied the Entergy System and its ultimate consumers the benefits of low-cost Entergy System generating capacity, and (c) violated the provision of the System Agreement that prohibits sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. In April 2016 the FERC issued orders addressing the requests for rehearing filed in July 2012 and the ALJ’s August 2013 initial decision. The first order denies Entergy’s request for rehearing and affirms FERC’s earlier rulings that Entergy’s original methodology for allocating energy costs to the opportunity sales was incorrect and, as a result, Entergy Arkansas must make payments to the other Utility operating companies to put them in the same position that they would have been in absent the incorrect allocation. The FERC clarified that interest should be included with the payments. The second order affirmed in part, and reversed in part, the rulings in the ALJ’s initial decision regarding the methodology that should be used to calculate the payments Entergy Arkansas is to make to the other Utility operating companies. The FERC affirmed the ALJ’s ruling that a full re-run of intra-system bills should be performed, but required that methodology be modified so that the sales have the same priority for purposes of energy allocation as joint account sales. The FERC reversed the ALJ’s decision that any payments by Entergy Arkansas should be reduced by 20% . The FERC also reversed the ALJ’s decision that adjustments to other System Agreement service schedules and excess bandwidth payments should not be taken into account when calculating the payments to be made by Entergy Arkansas. The FERC held that such adjustments and excess bandwidth payments should be taken into account, but ordered further proceedings before an ALJ to address whether a cap on any reduction due to bandwidth payments was necessary and to implement the other adjustments to the calculation methodology. The effect of the FERC’s decisions, if upheld, is that Entergy Arkansas will make payments to some or all of the other Utility operating companies. As part of the further proceedings required by the FERC, Entergy will re-run intra-system bills for a ten-year period (2000-2009) to quantify the effects of the FERC's rulings. The ALJ will issue an initial decision and FERC will issue an order reviewing that decision. No payments will be made or received by the Utility operating companies until the FERC issues an order reviewing that initial decision and Entergy submits a subsequent filing to comply with that order. Because further proceedings are required, the amount and recipients of payments by Entergy Arkansas are unknown at this time. Based on testimony previously submitted in the case, however, in the first quarter 2016 Entergy Arkansas recorded a liability of $87 million for its estimated increased costs and payment to the other Utility operating companies, including interest. This estimate is subject to change depending on how the FERC resolves the issues that are still outstanding in the case. Entergy Arkansas’s increased costs will be attributed to Entergy Arkansas’s retail and wholesale businesses, and it is not probable that Entergy Arkansas will recover the wholesale portion. Therefore Entergy Arkansas recorded a regulatory asset of approximately $75 million , which represents its estimate of the retail portion of the costs.
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 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. 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. A procedural schedule has not been established for this proceeding, and discovery from intervenors 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. 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. 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. Entergy Texas requested that the refund be made to most customers over a four-month period beginning June 2016. 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, 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 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. Entergy Arkansas plans to make its first formula rate plan filing in July 2016 for rates effective with the first billing cycle of January 2017. Filings with the LPSC Retail Rates - Electric 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 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 has 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. 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 , subject to closing adjustments, and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. 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. Discovery regarding these issues is pending, but a procedural schedule has not been established for addressing the outstanding issues. 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 terms of the gas rate stabilization plan for an additional three-year term. A procedural schedule has not been established. 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 shows a $32.6 million rate increase is 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. The filing is currently subject to MPSC review. In April 2016 the Mississippi Public Utilities Staff filed a letter disputing the formula rate plan evaluation report subject to its continued review of the submittal. A final order is expected in second quarter 2016, with the resulting rates effective mid-year 2016. Pursuant to the terms of the formula rate plan, Entergy Mississippi also submitted an informational look-back filing for 2015 that showed Entergy Mississippi’s 2015 earned return was within the formula rate plan bandwidth. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6 as well as the revenue requirement associated with the acquisition of Power Block 1 of Union Power Station. In March 2016, Entergy New Orleans acquired Power Block 1 of Union Power Station for approximately $237 million , subject to closing adjustments, and initiated recovery of these costs with March 2016 bills. Filings with the PUCT 2011 Rate Case See the Form 10-K for discussion of Entergy Texas’s 2011 rate case. As discussed in the Form 10-K, several parties, including Entergy Texas, appealed various aspects of the PUCT’s order to the Travis County District Court. In October 2014 the Travis County District Court issued an order upholding the PUCT’s decision except as to the line-loss factor issue referenced in the Form 10-K, which was found in favor of Entergy Texas. In November 2014, Entergy Texas and other parties, including the PUCT, appealed the Travis County District Court decision to the Third Court of Appeals. Oral argument before the court panel was held in September 2015. In April 2016 the Third Court of Appeals issued its opinion affirming the District Court’s decision on all points. Entergy Texas plans to petition the Texas Supreme Court to hear its appeal of the Third Court’s ruling. Other Filings In September 2015, Entergy Texas filed for a transmission cost recovery factor rider requesting a $13 million increase, incremental to base rates. Testimony was filed in November 2015, with the PUCT staff and other parties proposing various disallowances involving, among other things, MISO charges, vegetation management costs, and bad debt expenses that would reduce the requested increase by approximately $2 million . In addition to those recommended disallowances, a number of parties recommended that Entergy Texas’s request be reduced by an additional $3.4 million to account for load growth since base rates were last set. A hearing on the merits was held in December 2015. In February 2016 a State Office of Administrative Hearings ALJ issued a proposal for decision recommending that the PUCT disallow approximately $2 million from Entergy Texas’s $13 million request, but recommending that the PUCT not accept the load growth offset. In May 2016 the PUCT deferred final consideration of Entergy Texas’s TCRF application and opened the record to consider additional evidence to be provided by Entergy Texas and potentially other parties regarding the rate-making treatment of spare transmission-level transformers that are transferred among the Utility operating companies. It is not known when the PUCT will take up the merits of this matter, but Entergy Texas was granted interim rates as of April 14, 2016 whenever a final order is issued setting those rates. System Agreement Cost Equalization Proceedings Rough Production Cost Equalization Rates 2015 Rate Filing Based on Calendar Year 2014 Production Costs In May 2015, Entergy filed with the FERC the 2015 rates in accordance with the FERC’s orders in the System Agreement proceeding. The filing shows that no payments and receipts are required in 2015 to implement the FERC’s remedy based on calendar year 2014 production costs. Several parties intervened in the proceeding and the LPSC and City Council intervened and filed comments. In October 2015 the FERC accepted the 2015 rates for filing, suspended them for a nominal period, to become effective June 1, 2015, as requested, subject to refund, and set them for hearing and settlement judge procedures. In March 2016, Entergy Services filed a settlement at the FERC resolving the 2015 rate filing. In the settlement, the parties did not dispute the 2015 rates as calculated with no payments or receipts. Pursuant to the settlement, the 2015 rates are subject to a recalculation and compliance filing upon resolution of other ongoing bandwidth-related proceedings. Interruptible Load Proceedings See the Form 10-K for a discussion of the interruptible load proceeding. In April 2016 the FERC issued an order on remand that addressed the December 2014 decision by the D.C. Circuit in the interruptible load proceeding. The order on remand affirmed the FERC’s denial of refunds for the 15-month refund effective period. The FERC explained and clarified its policies regarding refunds and concluded that the evidence in the record demonstrated that the relevant equitable factors favored not requiring refunds in this case. The FERC also noted that, under Section 206(c) of the Federal Power Act, in a Section 206 proceeding involving two or more electric utility companies of a registered holding company system, the FERC may order refunds only if it determines the refunds would not cause the registered holding company to experience any reduction in revenues resulting from an inability of an electric utility company in the system to recover the resulting increase in costs. The FERC stated it was not able to find that the Entergy system would not experience a reduction in revenues if refunds were awarded in this proceeding, which further supported the denial of refunds. Entergy Arkansas Opportunity Sales Proceedings See the Form 10-K for a discussion of the proceeding initiated at the FERC by the LPSC in June 2009 in which the LPSC initially requested that the FERC determine that certain of Entergy Arkansas’s sales of electric energy to third parties: (a) violated the provisions of the System Agreement that allocate the energy generated by Entergy System resources, (b) imprudently denied the Entergy System and its ultimate consumers the benefits of low-cost Entergy System generating capacity, and (c) violated the provision of the System Agreement that prohibits sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. In April 2016 the FERC issued orders addressing the requests for rehearing filed in July 2012 and the ALJ’s August 2013 initial decision. The first order denies Entergy’s request for rehearing and affirms FERC’s earlier rulings that Entergy’s original methodology for allocating energy costs to the opportunity sales was incorrect and, as a result, Entergy Arkansas must make payments to the other Utility operating companies to put them in the same position that they would have been in absent the incorrect allocation. The FERC clarified that interest should be included with the payments. The second order affirmed in part, and reversed in part, the rulings in the ALJ’s initial decision regarding the methodology that should be used to calculate the payments Entergy Arkansas is to make to the other Utility operating companies. The FERC affirmed the ALJ’s ruling that a full re-run of intra-system bills should be performed, but required that methodology be modified so that the sales have the same priority for purposes of energy allocation as joint account sales. The FERC reversed the ALJ’s decision that any payments by Entergy Arkansas should be reduced by 20% . The FERC also reversed the ALJ’s decision that adjustments to other System Agreement service schedules and excess bandwidth payments should not be taken into account when calculating the payments to be made by Entergy Arkansas. The FERC held that such adjustments and excess bandwidth payments should be taken into account, but ordered further proceedings before an ALJ to address whether a cap on any reduction due to bandwidth payments was necessary and to implement the other adjustments to the calculation methodology. The effect of the FERC’s decisions, if upheld, is that Entergy Arkansas will make payments to some or all of the other Utility operating companies. As part of the further proceedings required by the FERC, Entergy will re-run intra-system bills for a ten-year period (2000-2009) to quantify the effects of the FERC's rulings. The ALJ will issue an initial decision and FERC will issue an order reviewing that decision. No payments will be made or received by the Utility operating companies until the FERC issues an order reviewing that initial decision and Entergy submits a subsequent filing to comply with that order. Because further proceedings are required, the amount and recipients of payments by Entergy Arkansas are unknown at this time. Based on testimony previously submitted in the case, however, in the first quarter 2016 Entergy Arkansas recorded a liability of $87 million for its estimated increased costs and payment to the other Utility operating companies, including interest. This estimate is subject to change depending on how the FERC resolves the issues that are still outstanding in the case. Entergy Arkansas’s increased costs will be attributed to Entergy Arkansas’s retail and wholesale businesses, and it is not probable that Entergy Arkansas will recover the wholesale portion. Therefore Entergy Arkansas recorded a regulatory asset of approximately $75 million , which represents its estimate of the retail portion of the costs.
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 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. 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. A procedural schedule has not been established for this proceeding, and discovery from intervenors 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. 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. 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. Entergy Texas requested that the refund be made to most customers over a four-month period beginning June 2016. 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, 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 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. Entergy Arkansas plans to make its first formula rate plan filing in July 2016 for rates effective with the first billing cycle of January 2017. Filings with the LPSC Retail Rates - Electric 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 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 has 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. 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 , subject to closing adjustments, and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. 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. Discovery regarding these issues is pending, but a procedural schedule has not been established for addressing the outstanding issues. 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 terms of the gas rate stabilization plan for an additional three-year term. A procedural schedule has not been established. 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 shows a $32.6 million rate increase is 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. The filing is currently subject to MPSC review. In April 2016 the Mississippi Public Utilities Staff filed a letter disputing the formula rate plan evaluation report subject to its continued review of the submittal. A final order is expected in second quarter 2016, with the resulting rates effective mid-year 2016. Pursuant to the terms of the formula rate plan, Entergy Mississippi also submitted an informational look-back filing for 2015 that showed Entergy Mississippi’s 2015 earned return was within the formula rate plan bandwidth. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6 as well as the revenue requirement associated with the acquisition of Power Block 1 of Union Power Station. In March 2016, Entergy New Orleans acquired Power Block 1 of Union Power Station for approximately $237 million , subject to closing adjustments, and initiated recovery of these costs with March 2016 bills. Filings with the PUCT 2011 Rate Case See the Form 10-K for discussion of Entergy Texas’s 2011 rate case. As discussed in the Form 10-K, several parties, including Entergy Texas, appealed various aspects of the PUCT’s order to the Travis County District Court. In October 2014 the Travis County District Court issued an order upholding the PUCT’s decision except as to the line-loss factor issue referenced in the Form 10-K, which was found in favor of Entergy Texas. In November 2014, Entergy Texas and other parties, including the PUCT, appealed the Travis County District Court decision to the Third Court of Appeals. Oral argument before the court panel was held in September 2015. In April 2016 the Third Court of Appeals issued its opinion affirming the District Court’s decision on all points. Entergy Texas plans to petition the Texas Supreme Court to hear its appeal of the Third Court’s ruling. Other Filings In September 2015, Entergy Texas filed for a transmission cost recovery factor rider requesting a $13 million increase, incremental to base rates. Testimony was filed in November 2015, with the PUCT staff and other parties proposing various disallowances involving, among other things, MISO charges, vegetation management costs, and bad debt expenses that would reduce the requested increase by approximately $2 million . In addition to those recommended disallowances, a number of parties recommended that Entergy Texas’s request be reduced by an additional $3.4 million to account for load growth since base rates were last set. A hearing on the merits was held in December 2015. In February 2016 a State Office of Administrative Hearings ALJ issued a proposal for decision recommending that the PUCT disallow approximately $2 million from Entergy Texas’s $13 million request, but recommending that the PUCT not accept the load growth offset. In May 2016 the PUCT deferred final consideration of Entergy Texas’s TCRF application and opened the record to consider additional evidence to be provided by Entergy Texas and potentially other parties regarding the rate-making treatment of spare transmission-level transformers that are transferred among the Utility operating companies. It is not known when the PUCT will take up the merits of this matter, but Entergy Texas was granted interim rates as of April 14, 2016 whenever a final order is issued setting those rates. System Agreement Cost Equalization Proceedings Rough Production Cost Equalization Rates 2015 Rate Filing Based on Calendar Year 2014 Production Costs In May 2015, Entergy filed with the FERC the 2015 rates in accordance with the FERC’s orders in the System Agreement proceeding. The filing shows that no payments and receipts are required in 2015 to implement the FERC’s remedy based on calendar year 2014 production costs. Several parties intervened in the proceeding and the LPSC and City Council intervened and filed comments. In October 2015 the FERC accepted the 2015 rates for filing, suspended them for a nominal period, to become effective June 1, 2015, as requested, subject to refund, and set them for hearing and settlement judge procedures. In March 2016, Entergy Services filed a settlement at the FERC resolving the 2015 rate filing. In the settlement, the parties did not dispute the 2015 rates as calculated with no payments or receipts. Pursuant to the settlement, the 2015 rates are subject to a recalculation and compliance filing upon resolution of other ongoing bandwidth-related proceedings. Interruptible Load Proceedings See the Form 10-K for a discussion of the interruptible load proceeding. In April 2016 the FERC issued an order on remand that addressed the December 2014 decision by the D.C. Circuit in the interruptible load proceeding. The order on remand affirmed the FERC’s denial of refunds for the 15-month refund effective period. The FERC explained and clarified its policies regarding refunds and concluded that the evidence in the record demonstrated that the relevant equitable factors favored not requiring refunds in this case. The FERC also noted that, under Section 206(c) of the Federal Power Act, in a Section 206 proceeding involving two or more electric utility companies of a registered holding company system, the FERC may order refunds only if it determines the refunds would not cause the registered holding company to experience any reduction in revenues resulting from an inability of an electric utility company in the system to recover the resulting increase in costs. The FERC stated it was not able to find that the Entergy system would not experience a reduction in revenues if refunds were awarded in this proceeding, which further supported the denial of refunds. Entergy Arkansas Opportunity Sales Proceedings See the Form 10-K for a discussion of the proceeding initiated at the FERC by the LPSC in June 2009 in which the LPSC initially requested that the FERC determine that certain of Entergy Arkansas’s sales of electric energy to third parties: (a) violated the provisions of the System Agreement that allocate the energy generated by Entergy System resources, (b) imprudently denied the Entergy System and its ultimate consumers the benefits of low-cost Entergy System generating capacity, and (c) violated the provision of the System Agreement that prohibits sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. In April 2016 the FERC issued orders addressing the requests for rehearing filed in July 2012 and the ALJ’s August 2013 initial decision. The first order denies Entergy’s request for rehearing and affirms FERC’s earlier rulings that Entergy’s original methodology for allocating energy costs to the opportunity sales was incorrect and, as a result, Entergy Arkansas must make payments to the other Utility operating companies to put them in the same position that they would have been in absent the incorrect allocation. The FERC clarified that interest should be included with the payments. The second order affirmed in part, and reversed in part, the rulings in the ALJ’s initial decision regarding the methodology that should be used to calculate the payments Entergy Arkansas is to make to the other Utility operating companies. The FERC affirmed the ALJ’s ruling that a full re-run of intra-system bills should be performed, but required that methodology be modified so that the sales have the same priority for purposes of energy allocation as joint account sales. The FERC reversed the ALJ’s decision that any payments by Entergy Arkansas should be reduced by 20% . The FERC also reversed the ALJ’s decision that adjustments to other System Agreement service schedules and excess bandwidth payments should not be taken into account when calculating the payments to be made by Entergy Arkansas. The FERC held that such adjustments and excess bandwidth payments should be taken into account, but ordered further proceedings before an ALJ to address whether a cap on any reduction due to bandwidth payments was necessary and to implement the other adjustments to the calculation methodology. The effect of the FERC’s decisions, if upheld, is that Entergy Arkansas will make payments to some or all of the other Utility operating companies. As part of the further proceedings required by the FERC, Entergy will re-run intra-system bills for a ten-year period (2000-2009) to quantify the effects of the FERC's rulings. The ALJ will issue an initial decision and FERC will issue an order reviewing that decision. No payments will be made or received by the Utility operating companies until the FERC issues an order reviewing that initial decision and Entergy submits a subsequent filing to comply with that order. Because further proceedings are required, the amount and recipients of payments by Entergy Arkansas are unknown at this time. Based on testimony previously submitted in the case, however, in the first quarter 2016 Entergy Arkansas recorded a liability of $87 million for its estimated increased costs and payment to the other Utility operating companies, including interest. This estimate is subject to change depending on how the FERC resolves the issues that are still outstanding in the case. Entergy Arkansas’s increased costs will be attributed to Entergy Arkansas’s retail and wholesale businesses, and it is not probable that Entergy Arkansas will recover the wholesale portion. Therefore Entergy Arkansas recorded a regulatory asset of approximately $75 million , which represents its estimate of the retail portion of the costs.
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 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. 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. A procedural schedule has not been established for this proceeding, and discovery from intervenors 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. 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. 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. Entergy Texas requested that the refund be made to most customers over a four-month period beginning June 2016. 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, 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 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. Entergy Arkansas plans to make its first formula rate plan filing in July 2016 for rates effective with the first billing cycle of January 2017. Filings with the LPSC Retail Rates - Electric 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 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 has 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. 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 , subject to closing adjustments, and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. 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. Discovery regarding these issues is pending, but a procedural schedule has not been established for addressing the outstanding issues. 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 terms of the gas rate stabilization plan for an additional three-year term. A procedural schedule has not been established. 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 shows a $32.6 million rate increase is 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. The filing is currently subject to MPSC review. In April 2016 the Mississippi Public Utilities Staff filed a letter disputing the formula rate plan evaluation report subject to its continued review of the submittal. A final order is expected in second quarter 2016, with the resulting rates effective mid-year 2016. Pursuant to the terms of the formula rate plan, Entergy Mississippi also submitted an informational look-back filing for 2015 that showed Entergy Mississippi’s 2015 earned return was within the formula rate plan bandwidth. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6 as well as the revenue requirement associated with the acquisition of Power Block 1 of Union Power Station. In March 2016, Entergy New Orleans acquired Power Block 1 of Union Power Station for approximately $237 million , subject to closing adjustments, and initiated recovery of these costs with March 2016 bills. Filings with the PUCT 2011 Rate Case See the Form 10-K for discussion of Entergy Texas’s 2011 rate case. As discussed in the Form 10-K, several parties, including Entergy Texas, appealed various aspects of the PUCT’s order to the Travis County District Court. In October 2014 the Travis County District Court issued an order upholding the PUCT’s decision except as to the line-loss factor issue referenced in the Form 10-K, which was found in favor of Entergy Texas. In November 2014, Entergy Texas and other parties, including the PUCT, appealed the Travis County District Court decision to the Third Court of Appeals. Oral argument before the court panel was held in September 2015. In April 2016 the Third Court of Appeals issued its opinion affirming the District Court’s decision on all points. Entergy Texas plans to petition the Texas Supreme Court to hear its appeal of the Third Court’s ruling. Other Filings In September 2015, Entergy Texas filed for a transmission cost recovery factor rider requesting a $13 million increase, incremental to base rates. Testimony was filed in November 2015, with the PUCT staff and other parties proposing various disallowances involving, among other things, MISO charges, vegetation management costs, and bad debt expenses that would reduce the requested increase by approximately $2 million . In addition to those recommended disallowances, a number of parties recommended that Entergy Texas’s request be reduced by an additional $3.4 million to account for load growth since base rates were last set. A hearing on the merits was held in December 2015. In February 2016 a State Office of Administrative Hearings ALJ issued a proposal for decision recommending that the PUCT disallow approximately $2 million from Entergy Texas’s $13 million request, but recommending that the PUCT not accept the load growth offset. In May 2016 the PUCT deferred final consideration of Entergy Texas’s TCRF application and opened the record to consider additional evidence to be provided by Entergy Texas and potentially other parties regarding the rate-making treatment of spare transmission-level transformers that are transferred among the Utility operating companies. It is not known when the PUCT will take up the merits of this matter, but Entergy Texas was granted interim rates as of April 14, 2016 whenever a final order is issued setting those rates. System Agreement Cost Equalization Proceedings Rough Production Cost Equalization Rates 2015 Rate Filing Based on Calendar Year 2014 Production Costs In May 2015, Entergy filed with the FERC the 2015 rates in accordance with the FERC’s orders in the System Agreement proceeding. The filing shows that no payments and receipts are required in 2015 to implement the FERC’s remedy based on calendar year 2014 production costs. Several parties intervened in the proceeding and the LPSC and City Council intervened and filed comments. In October 2015 the FERC accepted the 2015 rates for filing, suspended them for a nominal period, to become effective June 1, 2015, as requested, subject to refund, and set them for hearing and settlement judge procedures. In March 2016, Entergy Services filed a settlement at the FERC resolving the 2015 rate filing. In the settlement, the parties did not dispute the 2015 rates as calculated with no payments or receipts. Pursuant to the settlement, the 2015 rates are subject to a recalculation and compliance filing upon resolution of other ongoing bandwidth-related proceedings. Interruptible Load Proceedings See the Form 10-K for a discussion of the interruptible load proceeding. In April 2016 the FERC issued an order on remand that addressed the December 2014 decision by the D.C. Circuit in the interruptible load proceeding. The order on remand affirmed the FERC’s denial of refunds for the 15-month refund effective period. The FERC explained and clarified its policies regarding refunds and concluded that the evidence in the record demonstrated that the relevant equitable factors favored not requiring refunds in this case. The FERC also noted that, under Section 206(c) of the Federal Power Act, in a Section 206 proceeding involving two or more electric utility companies of a registered holding company system, the FERC may order refunds only if it determines the refunds would not cause the registered holding company to experience any reduction in revenues resulting from an inability of an electric utility company in the system to recover the resulting increase in costs. The FERC stated it was not able to find that the Entergy system would not experience a reduction in revenues if refunds were awarded in this proceeding, which further supported the denial of refunds. Entergy Arkansas Opportunity Sales Proceedings See the Form 10-K for a discussion of the proceeding initiated at the FERC by the LPSC in June 2009 in which the LPSC initially requested that the FERC determine that certain of Entergy Arkansas’s sales of electric energy to third parties: (a) violated the provisions of the System Agreement that allocate the energy generated by Entergy System resources, (b) imprudently denied the Entergy System and its ultimate consumers the benefits of low-cost Entergy System generating capacity, and (c) violated the provision of the System Agreement that prohibits sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. In April 2016 the FERC issued orders addressing the requests for rehearing filed in July 2012 and the ALJ’s August 2013 initial decision. The first order denies Entergy’s request for rehearing and affirms FERC’s earlier rulings that Entergy’s original methodology for allocating energy costs to the opportunity sales was incorrect and, as a result, Entergy Arkansas must make payments to the other Utility operating companies to put them in the same position that they would have been in absent the incorrect allocation. The FERC clarified that interest should be included with the payments. The second order affirmed in part, and reversed in part, the rulings in the ALJ’s initial decision regarding the methodology that should be used to calculate the payments Entergy Arkansas is to make to the other Utility operating companies. The FERC affirmed the ALJ’s ruling that a full re-run of intra-system bills should be performed, but required that methodology be modified so that the sales have the same priority for purposes of energy allocation as joint account sales. The FERC reversed the ALJ’s decision that any payments by Entergy Arkansas should be reduced by 20% . The FERC also reversed the ALJ’s decision that adjustments to other System Agreement service schedules and excess bandwidth payments should not be taken into account when calculating the payments to be made by Entergy Arkansas. The FERC held that such adjustments and excess bandwidth payments should be taken into account, but ordered further proceedings before an ALJ to address whether a cap on any reduction due to bandwidth payments was necessary and to implement the other adjustments to the calculation methodology. The effect of the FERC’s decisions, if upheld, is that Entergy Arkansas will make payments to some or all of the other Utility operating companies. As part of the further proceedings required by the FERC, Entergy will re-run intra-system bills for a ten-year period (2000-2009) to quantify the effects of the FERC's rulings. The ALJ will issue an initial decision and FERC will issue an order reviewing that decision. No payments will be made or received by the Utility operating companies until the FERC issues an order reviewing that initial decision and Entergy submits a subsequent filing to comply with that order. Because further proceedings are required, the amount and recipients of payments by Entergy Arkansas are unknown at this time. Based on testimony previously submitted in the case, however, in the first quarter 2016 Entergy Arkansas recorded a liability of $87 million for its estimated increased costs and payment to the other Utility operating companies, including interest. This estimate is subject to change depending on how the FERC resolves the issues that are still outstanding in the case. Entergy Arkansas’s increased costs will be attributed to Entergy Arkansas’s retail and wholesale businesses, and it is not probable that Entergy Arkansas will recover the wholesale portion. Therefore Entergy Arkansas recorded a regulatory asset of approximately $75 million , which represents its estimate of the retail portion of the costs.
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 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. 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. A procedural schedule has not been established for this proceeding, and discovery from intervenors 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. 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. 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. Entergy Texas requested that the refund be made to most customers over a four-month period beginning June 2016. 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, 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 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. Entergy Arkansas plans to make its first formula rate plan filing in July 2016 for rates effective with the first billing cycle of January 2017. Filings with the LPSC Retail Rates - Electric 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 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 has 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. 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 , subject to closing adjustments, and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. 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. Discovery regarding these issues is pending, but a procedural schedule has not been established for addressing the outstanding issues. 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 terms of the gas rate stabilization plan for an additional three-year term. A procedural schedule has not been established. 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 shows a $32.6 million rate increase is 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. The filing is currently subject to MPSC review. In April 2016 the Mississippi Public Utilities Staff filed a letter disputing the formula rate plan evaluation report subject to its continued review of the submittal. A final order is expected in second quarter 2016, with the resulting rates effective mid-year 2016. Pursuant to the terms of the formula rate plan, Entergy Mississippi also submitted an informational look-back filing for 2015 that showed Entergy Mississippi’s 2015 earned return was within the formula rate plan bandwidth. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6 as well as the revenue requirement associated with the acquisition of Power Block 1 of Union Power Station. In March 2016, Entergy New Orleans acquired Power Block 1 of Union Power Station for approximately $237 million , subject to closing adjustments, and initiated recovery of these costs with March 2016 bills. Filings with the PUCT 2011 Rate Case See the Form 10-K for discussion of Entergy Texas’s 2011 rate case. As discussed in the Form 10-K, several parties, including Entergy Texas, appealed various aspects of the PUCT’s order to the Travis County District Court. In October 2014 the Travis County District Court issued an order upholding the PUCT’s decision except as to the line-loss factor issue referenced in the Form 10-K, which was found in favor of Entergy Texas. In November 2014, Entergy Texas and other parties, including the PUCT, appealed the Travis County District Court decision to the Third Court of Appeals. Oral argument before the court panel was held in September 2015. In April 2016 the Third Court of Appeals issued its opinion affirming the District Court’s decision on all points. Entergy Texas plans to petition the Texas Supreme Court to hear its appeal of the Third Court’s ruling. Other Filings In September 2015, Entergy Texas filed for a transmission cost recovery factor rider requesting a $13 million increase, incremental to base rates. Testimony was filed in November 2015, with the PUCT staff and other parties proposing various disallowances involving, among other things, MISO charges, vegetation management costs, and bad debt expenses that would reduce the requested increase by approximately $2 million . In addition to those recommended disallowances, a number of parties recommended that Entergy Texas’s request be reduced by an additional $3.4 million to account for load growth since base rates were last set. A hearing on the merits was held in December 2015. In February 2016 a State Office of Administrative Hearings ALJ issued a proposal for decision recommending that the PUCT disallow approximately $2 million from Entergy Texas’s $13 million request, but recommending that the PUCT not accept the load growth offset. In May 2016 the PUCT deferred final consideration of Entergy Texas’s TCRF application and opened the record to consider additional evidence to be provided by Entergy Texas and potentially other parties regarding the rate-making treatment of spare transmission-level transformers that are transferred among the Utility operating companies. It is not known when the PUCT will take up the merits of this matter, but Entergy Texas was granted interim rates as of April 14, 2016 whenever a final order is issued setting those rates. System Agreement Cost Equalization Proceedings Rough Production Cost Equalization Rates 2015 Rate Filing Based on Calendar Year 2014 Production Costs In May 2015, Entergy filed with the FERC the 2015 rates in accordance with the FERC’s orders in the System Agreement proceeding. The filing shows that no payments and receipts are required in 2015 to implement the FERC’s remedy based on calendar year 2014 production costs. Several parties intervened in the proceeding and the LPSC and City Council intervened and filed comments. In October 2015 the FERC accepted the 2015 rates for filing, suspended them for a nominal period, to become effective June 1, 2015, as requested, subject to refund, and set them for hearing and settlement judge procedures. In March 2016, Entergy Services filed a settlement at the FERC resolving the 2015 rate filing. In the settlement, the parties did not dispute the 2015 rates as calculated with no payments or receipts. Pursuant to the settlement, the 2015 rates are subject to a recalculation and compliance filing upon resolution of other ongoing bandwidth-related proceedings. Interruptible Load Proceedings See the Form 10-K for a discussion of the interruptible load proceeding. In April 2016 the FERC issued an order on remand that addressed the December 2014 decision by the D.C. Circuit in the interruptible load proceeding. The order on remand affirmed the FERC’s denial of refunds for the 15-month refund effective period. The FERC explained and clarified its policies regarding refunds and concluded that the evidence in the record demonstrated that the relevant equitable factors favored not requiring refunds in this case. The FERC also noted that, under Section 206(c) of the Federal Power Act, in a Section 206 proceeding involving two or more electric utility companies of a registered holding company system, the FERC may order refunds only if it determines the refunds would not cause the registered holding company to experience any reduction in revenues resulting from an inability of an electric utility company in the system to recover the resulting increase in costs. The FERC stated it was not able to find that the Entergy system would not experience a reduction in revenues if refunds were awarded in this proceeding, which further supported the denial of refunds. Entergy Arkansas Opportunity Sales Proceedings See the Form 10-K for a discussion of the proceeding initiated at the FERC by the LPSC in June 2009 in which the LPSC initially requested that the FERC determine that certain of Entergy Arkansas’s sales of electric energy to third parties: (a) violated the provisions of the System Agreement that allocate the energy generated by Entergy System resources, (b) imprudently denied the Entergy System and its ultimate consumers the benefits of low-cost Entergy System generating capacity, and (c) violated the provision of the System Agreement that prohibits sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. In April 2016 the FERC issued orders addressing the requests for rehearing filed in July 2012 and the ALJ’s August 2013 initial decision. The first order denies Entergy’s request for rehearing and affirms FERC’s earlier rulings that Entergy’s original methodology for allocating energy costs to the opportunity sales was incorrect and, as a result, Entergy Arkansas must make payments to the other Utility operating companies to put them in the same position that they would have been in absent the incorrect allocation. The FERC clarified that interest should be included with the payments. The second order affirmed in part, and reversed in part, the rulings in the ALJ’s initial decision regarding the methodology that should be used to calculate the payments Entergy Arkansas is to make to the other Utility operating companies. The FERC affirmed the ALJ’s ruling that a full re-run of intra-system bills should be performed, but required that methodology be modified so that the sales have the same priority for purposes of energy allocation as joint account sales. The FERC reversed the ALJ’s decision that any payments by Entergy Arkansas should be reduced by 20% . The FERC also reversed the ALJ’s decision that adjustments to other System Agreement service schedules and excess bandwidth payments should not be taken into account when calculating the payments to be made by Entergy Arkansas. The FERC held that such adjustments and excess bandwidth payments should be taken into account, but ordered further proceedings before an ALJ to address whether a cap on any reduction due to bandwidth payments was necessary and to implement the other adjustments to the calculation methodology. The effect of the FERC’s decisions, if upheld, is that Entergy Arkansas will make payments to some or all of the other Utility operating companies. As part of the further proceedings required by the FERC, Entergy will re-run intra-system bills for a ten-year period (2000-2009) to quantify the effects of the FERC's rulings. The ALJ will issue an initial decision and FERC will issue an order reviewing that decision. No payments will be made or received by the Utility operating companies until the FERC issues an order reviewing that initial decision and Entergy submits a subsequent filing to comply with that order. Because further proceedings are required, the amount and recipients of payments by Entergy Arkansas are unknown at this time. Based on testimony previously submitted in the case, however, in the first quarter 2016 Entergy Arkansas recorded a liability of $87 million for its estimated increased costs and payment to the other Utility operating companies, including interest. This estimate is subject to change depending on how the FERC resolves the issues that are still outstanding in the case. Entergy Arkansas’s increased costs will be attributed to Entergy Arkansas’s retail and wholesale businesses, and it is not probable that Entergy Arkansas will recover the wholesale portion. Therefore Entergy Arkansas recorded a regulatory asset of approximately $75 million , which represents its estimate of the retail portion of the costs.

Equity

Equity	3 Months Ended
	Mar. 31, 2016
Equity	EQUITY (Entergy Corporation and Entergy Louisiana) Common Stock Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Three Months Ended March 31, 2016 2015 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $230.0 178.6 $1.29 $298.1 179.7 $1.66 Average dilutive effect of: Stock options 0.1 — 0.5 (0.01 ) Other equity plans 0.3 (0.01 ) 0.3 — Diluted earnings per share $230.0 179.0 $1.28 $298.1 180.5 $1.65 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 6.1 million for the three months ended March 31, 2016 and approximately 3.5 million for the three months ended March 31, 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. Treasury Stock During the three months ended March 31, 2016 , Entergy Corporation issued 332,576 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 three months ended March 31, 2016. Retained Earnings On April 6, 2016, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.85 per share, payable on June 1, 2016, to holders of record as of May 12, 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 March 31, 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 90,307 — 25,032 (284 ) 115,055 Amounts reclassified from accumulated other comprehensive income (loss) (99,813 ) 7,562 (1,963 ) — (94,214 ) Net other comprehensive income (loss) for the period (9,506 ) 7,562 23,069 (284 ) 20,841 Ending balance, March 31, 2016 $96,464 ($459,042 ) $390,626 $1,744 $29,792 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 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 (20,896 ) 13 12,658 (551 ) (8,776 ) Amounts reclassified from accumulated other comprehensive income (loss) (8,434 ) 8,435 (8,655 ) — (8,654 ) Net other comprehensive income (loss) for the period (29,330 ) 8,448 4,003 (551 ) (17,430 ) Ending balance, March 31, 2015 $68,788 ($561,341 ) $430,698 $2,118 ($59,737 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended March 31, 2016: Pension and Other (In Thousands) Beginning balance, January 1, 2016 ($56,412 ) Amounts reclassified from accumulated other (263 ) Net other comprehensive income (loss) for the period (263 ) Ending balance, March 31, 2016 ($56,675 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended March 31, 2015: Pension and Other (In Thousands) Beginning balance, January 1, 2015 ($79,223 ) Amounts reclassified from accumulated other 380 Net other comprehensive income (loss) for the period 380 Ending balance, March 31, 2015 ($78,843 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended March 31, 2016 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $153,958 Competitive business operating revenues Interest rate swaps (400 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 153,558 (53,745 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $99,813 Pension and other postretirement liabilities Amortization of prior-service credit $7,355 (a) Amortization of loss (15,175 ) (a) Total amortization (7,820 ) 258 Income taxes Total amortization (net of tax) ($7,562 ) Net unrealized investment gain (loss) Realized gain (loss) $3,850 Interest and investment income (1,887 ) Income taxes Total realized investment gain (loss) (net of tax) $1,963 Total reclassifications for the period (net of tax) $94,214 (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 March 31, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $13,522 Competitive business operating revenues Interest rate swaps (546 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 12,976 (4,542 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $8,434 Pension and other postretirement liabilities Amortization of prior-service credit $5,986 (a) Amortization of loss (17,588 ) (a) Total amortization (11,602 ) 3,167 Income taxes Total amortization (net of tax) ($8,435 ) Net unrealized investment gain (loss) Realized gain (loss) $16,970 Interest and investment income (8,315 ) Income taxes Total realized investment gain (loss) (net of tax) $8,655 Total reclassifications for the period (net of tax) $8,654 (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 March 31, 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 (1,569 ) (a) Total amortization 378 (115 ) Income taxes Total amortization (net of tax) 263 Total reclassifications for the period (net of tax) $263 (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 March 31, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,867 (a) Amortization of loss (2,535 ) (a) Total amortization (668 ) 288 Income taxes Total amortization (net of tax) (380 ) Total reclassifications for the period (net of tax) ($380 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.
Entergy Louisiana [Member]
Equity	EQUITY (Entergy Corporation and Entergy Louisiana) Common Stock Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Three Months Ended March 31, 2016 2015 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $230.0 178.6 $1.29 $298.1 179.7 $1.66 Average dilutive effect of: Stock options 0.1 — 0.5 (0.01 ) Other equity plans 0.3 (0.01 ) 0.3 — Diluted earnings per share $230.0 179.0 $1.28 $298.1 180.5 $1.65 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 6.1 million for the three months ended March 31, 2016 and approximately 3.5 million for the three months ended March 31, 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. Treasury Stock During the three months ended March 31, 2016 , Entergy Corporation issued 332,576 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 three months ended March 31, 2016. Retained Earnings On April 6, 2016, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.85 per share, payable on June 1, 2016, to holders of record as of May 12, 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 March 31, 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 90,307 — 25,032 (284 ) 115,055 Amounts reclassified from accumulated other comprehensive income (loss) (99,813 ) 7,562 (1,963 ) — (94,214 ) Net other comprehensive income (loss) for the period (9,506 ) 7,562 23,069 (284 ) 20,841 Ending balance, March 31, 2016 $96,464 ($459,042 ) $390,626 $1,744 $29,792 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 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 (20,896 ) 13 12,658 (551 ) (8,776 ) Amounts reclassified from accumulated other comprehensive income (loss) (8,434 ) 8,435 (8,655 ) — (8,654 ) Net other comprehensive income (loss) for the period (29,330 ) 8,448 4,003 (551 ) (17,430 ) Ending balance, March 31, 2015 $68,788 ($561,341 ) $430,698 $2,118 ($59,737 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended March 31, 2016: Pension and Other (In Thousands) Beginning balance, January 1, 2016 ($56,412 ) Amounts reclassified from accumulated other (263 ) Net other comprehensive income (loss) for the period (263 ) Ending balance, March 31, 2016 ($56,675 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended March 31, 2015: Pension and Other (In Thousands) Beginning balance, January 1, 2015 ($79,223 ) Amounts reclassified from accumulated other 380 Net other comprehensive income (loss) for the period 380 Ending balance, March 31, 2015 ($78,843 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended March 31, 2016 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $153,958 Competitive business operating revenues Interest rate swaps (400 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 153,558 (53,745 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $99,813 Pension and other postretirement liabilities Amortization of prior-service credit $7,355 (a) Amortization of loss (15,175 ) (a) Total amortization (7,820 ) 258 Income taxes Total amortization (net of tax) ($7,562 ) Net unrealized investment gain (loss) Realized gain (loss) $3,850 Interest and investment income (1,887 ) Income taxes Total realized investment gain (loss) (net of tax) $1,963 Total reclassifications for the period (net of tax) $94,214 (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 March 31, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $13,522 Competitive business operating revenues Interest rate swaps (546 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 12,976 (4,542 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $8,434 Pension and other postretirement liabilities Amortization of prior-service credit $5,986 (a) Amortization of loss (17,588 ) (a) Total amortization (11,602 ) 3,167 Income taxes Total amortization (net of tax) ($8,435 ) Net unrealized investment gain (loss) Realized gain (loss) $16,970 Interest and investment income (8,315 ) Income taxes Total realized investment gain (loss) (net of tax) $8,655 Total reclassifications for the period (net of tax) $8,654 (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 March 31, 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 (1,569 ) (a) Total amortization 378 (115 ) Income taxes Total amortization (net of tax) 263 Total reclassifications for the period (net of tax) $263 (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 March 31, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,867 (a) Amortization of loss (2,535 ) (a) Total amortization (668 ) 288 Income taxes Total amortization (net of tax) (380 ) Total reclassifications for the period (net of tax) ($380 ) (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	3 Months Ended
	Mar. 31, 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 2020. 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 0.275% 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 three months ended March 31, 2016 was 2.35% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $616 $7 $2,877 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 March 31, 2016 , Entergy Corporation had $578 million of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2016 was 1.14% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2016 Letters of Credit Outstanding as of March 31, 2016 Entergy Arkansas April 2016 $20 million (b) 1.93% $— $— Entergy Arkansas August 2020 $150 million (c) 1.68% $— $— Entergy Louisiana August 2020 $350 million (d) 1.68% $— $3.1 million Entergy Mississippi May 2016 $37.5 million (e) 1.93% $— $— Entergy Mississippi May 2016 $35 million (e) 1.93% $— $— Entergy Mississippi May 2016 $20 million (e) 1.93% $— $— Entergy Mississippi May 2016 $10 million (e) 1.93% $— $— Entergy New Orleans November 2018 $25 million 2.18% $— $— Entergy Texas August 2020 $150 million (f) 1.93% $— $1.3 million (a) The interest rate is the rate as of March 31, 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. The credit facility expired in April 2016. Entergy Arkansas plans to renew the credit facility. (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. Entergy Mississippi expects to renew its credit facilities prior to expiration. (f) 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 0.125% 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 March 31, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $7.0 million Entergy Mississippi $40 million 0.70% $4.4 million Entergy New Orleans $15 million 0.75% $6.2 million Entergy Texas $50 million 0.70% $5.6 million (a) The amount for Entergy Mississippi includes $0.4 million related to FTR exposure. See Note 8 to the financial statements herein for discussion of FTRs. 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 March 31, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee entered into 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 0.25% of the undrawn commitment amount. As of March 31, 2016 , $61 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the three months ended March 31, 2016 was 2.20% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also entered into 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 March 31, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of March 31, 2016 that would most likely apply to outstanding borrowings under the facility was 2.18% 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 March 31, 2016 : Company Expiration Date (a) Amount of Facility Weighted Average Interest Rate on Borrowings (b) Amount Outstanding as of March 31, 2016 (Dollars in Millions) Entergy Arkansas VIE June 2016 $85 n/a $— Entergy Louisiana River Bend VIE June 2016 $100 n/a $— Entergy Louisiana Waterford VIE June 2016 $90 1.86% $77.5 (c) System Energy VIE June 2016 $125 2.01% $111 (c) (a) Prior to expiration, the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy each plan to renew its credit facility. (b) 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. (c) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Louisiana VIEs and 0.125% of the undrawn commitment amount for the Entergy Arkansas 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 March 31, 2016 as follows: Company Description Amount Entergy Arkansas VIE 3.23% Series J due July 2016 $55 million 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 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 Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union purchase. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. 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 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 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 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 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 held in trust as of March 31, 2016 and were applied in April 2016 to the refunding of $198.68 million of outstanding series of 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. (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 Union Power Station. See Note 13 to the financial statements for discussion of the Union purchase. (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. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,296,872 $14,811,845 Entergy Arkansas $2,777,649 $2,726,079 Entergy Louisiana $5,620,234 $5,967,996 Entergy Mississippi $1,045,430 $1,100,469 Entergy New Orleans $449,892 $443,145 Entergy Texas $1,552,741 $1,702,601 System Energy $572,742 $550,080 (a) The values exclude lease obligations of $56 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. 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 2020. 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 0.275% 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 three months ended March 31, 2016 was 2.35% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $616 $7 $2,877 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 March 31, 2016 , Entergy Corporation had $578 million of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2016 was 1.14% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2016 Letters of Credit Outstanding as of March 31, 2016 Entergy Arkansas April 2016 $20 million (b) 1.93% $— $— Entergy Arkansas August 2020 $150 million (c) 1.68% $— $— Entergy Louisiana August 2020 $350 million (d) 1.68% $— $3.1 million Entergy Mississippi May 2016 $37.5 million (e) 1.93% $— $— Entergy Mississippi May 2016 $35 million (e) 1.93% $— $— Entergy Mississippi May 2016 $20 million (e) 1.93% $— $— Entergy Mississippi May 2016 $10 million (e) 1.93% $— $— Entergy New Orleans November 2018 $25 million 2.18% $— $— Entergy Texas August 2020 $150 million (f) 1.93% $— $1.3 million (a) The interest rate is the rate as of March 31, 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. The credit facility expired in April 2016. Entergy Arkansas plans to renew the credit facility. (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. Entergy Mississippi expects to renew its credit facilities prior to expiration. (f) 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 0.125% 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 March 31, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $7.0 million Entergy Mississippi $40 million 0.70% $4.4 million Entergy New Orleans $15 million 0.75% $6.2 million Entergy Texas $50 million 0.70% $5.6 million (a) The amount for Entergy Mississippi includes $0.4 million related to FTR exposure. See Note 8 to the financial statements herein for discussion of FTRs. 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 March 31, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee entered into 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 0.25% of the undrawn commitment amount. As of March 31, 2016 , $61 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the three months ended March 31, 2016 was 2.20% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also entered into 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 March 31, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of March 31, 2016 that would most likely apply to outstanding borrowings under the facility was 2.18% 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 March 31, 2016 : Company Expiration Date (a) Amount of Facility Weighted Average Interest Rate on Borrowings (b) Amount Outstanding as of March 31, 2016 (Dollars in Millions) Entergy Arkansas VIE June 2016 $85 n/a $— Entergy Louisiana River Bend VIE June 2016 $100 n/a $— Entergy Louisiana Waterford VIE June 2016 $90 1.86% $77.5 (c) System Energy VIE June 2016 $125 2.01% $111 (c) (a) Prior to expiration, the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy each plan to renew its credit facility. (b) 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. (c) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Louisiana VIEs and 0.125% of the undrawn commitment amount for the Entergy Arkansas 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 March 31, 2016 as follows: Company Description Amount Entergy Arkansas VIE 3.23% Series J due July 2016 $55 million 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 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 Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union purchase. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. 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 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 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 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 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 held in trust as of March 31, 2016 and were applied in April 2016 to the refunding of $198.68 million of outstanding series of 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. (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 Union Power Station. See Note 13 to the financial statements for discussion of the Union purchase. (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. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,296,872 $14,811,845 Entergy Arkansas $2,777,649 $2,726,079 Entergy Louisiana $5,620,234 $5,967,996 Entergy Mississippi $1,045,430 $1,100,469 Entergy New Orleans $449,892 $443,145 Entergy Texas $1,552,741 $1,702,601 System Energy $572,742 $550,080 (a) The values exclude lease obligations of $56 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. 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 2020. 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 0.275% 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 three months ended March 31, 2016 was 2.35% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $616 $7 $2,877 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 March 31, 2016 , Entergy Corporation had $578 million of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2016 was 1.14% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2016 Letters of Credit Outstanding as of March 31, 2016 Entergy Arkansas April 2016 $20 million (b) 1.93% $— $— Entergy Arkansas August 2020 $150 million (c) 1.68% $— $— Entergy Louisiana August 2020 $350 million (d) 1.68% $— $3.1 million Entergy Mississippi May 2016 $37.5 million (e) 1.93% $— $— Entergy Mississippi May 2016 $35 million (e) 1.93% $— $— Entergy Mississippi May 2016 $20 million (e) 1.93% $— $— Entergy Mississippi May 2016 $10 million (e) 1.93% $— $— Entergy New Orleans November 2018 $25 million 2.18% $— $— Entergy Texas August 2020 $150 million (f) 1.93% $— $1.3 million (a) The interest rate is the rate as of March 31, 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. The credit facility expired in April 2016. Entergy Arkansas plans to renew the credit facility. (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. Entergy Mississippi expects to renew its credit facilities prior to expiration. (f) 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 0.125% 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 March 31, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $7.0 million Entergy Mississippi $40 million 0.70% $4.4 million Entergy New Orleans $15 million 0.75% $6.2 million Entergy Texas $50 million 0.70% $5.6 million (a) The amount for Entergy Mississippi includes $0.4 million related to FTR exposure. See Note 8 to the financial statements herein for discussion of FTRs. 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 March 31, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee entered into 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 0.25% of the undrawn commitment amount. As of March 31, 2016 , $61 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the three months ended March 31, 2016 was 2.20% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also entered into 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 March 31, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of March 31, 2016 that would most likely apply to outstanding borrowings under the facility was 2.18% 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 March 31, 2016 : Company Expiration Date (a) Amount of Facility Weighted Average Interest Rate on Borrowings (b) Amount Outstanding as of March 31, 2016 (Dollars in Millions) Entergy Arkansas VIE June 2016 $85 n/a $— Entergy Louisiana River Bend VIE June 2016 $100 n/a $— Entergy Louisiana Waterford VIE June 2016 $90 1.86% $77.5 (c) System Energy VIE June 2016 $125 2.01% $111 (c) (a) Prior to expiration, the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy each plan to renew its credit facility. (b) 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. (c) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Louisiana VIEs and 0.125% of the undrawn commitment amount for the Entergy Arkansas 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 March 31, 2016 as follows: Company Description Amount Entergy Arkansas VIE 3.23% Series J due July 2016 $55 million 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 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 Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union purchase. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. 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 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 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 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 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 held in trust as of March 31, 2016 and were applied in April 2016 to the refunding of $198.68 million of outstanding series of 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. (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 Union Power Station. See Note 13 to the financial statements for discussion of the Union purchase. (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. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,296,872 $14,811,845 Entergy Arkansas $2,777,649 $2,726,079 Entergy Louisiana $5,620,234 $5,967,996 Entergy Mississippi $1,045,430 $1,100,469 Entergy New Orleans $449,892 $443,145 Entergy Texas $1,552,741 $1,702,601 System Energy $572,742 $550,080 (a) The values exclude lease obligations of $56 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. 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 2020. 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 0.275% 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 three months ended March 31, 2016 was 2.35% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $616 $7 $2,877 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 March 31, 2016 , Entergy Corporation had $578 million of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2016 was 1.14% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2016 Letters of Credit Outstanding as of March 31, 2016 Entergy Arkansas April 2016 $20 million (b) 1.93% $— $— Entergy Arkansas August 2020 $150 million (c) 1.68% $— $— Entergy Louisiana August 2020 $350 million (d) 1.68% $— $3.1 million Entergy Mississippi May 2016 $37.5 million (e) 1.93% $— $— Entergy Mississippi May 2016 $35 million (e) 1.93% $— $— Entergy Mississippi May 2016 $20 million (e) 1.93% $— $— Entergy Mississippi May 2016 $10 million (e) 1.93% $— $— Entergy New Orleans November 2018 $25 million 2.18% $— $— Entergy Texas August 2020 $150 million (f) 1.93% $— $1.3 million (a) The interest rate is the rate as of March 31, 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. The credit facility expired in April 2016. Entergy Arkansas plans to renew the credit facility. (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. Entergy Mississippi expects to renew its credit facilities prior to expiration. (f) 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 0.125% 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 March 31, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $7.0 million Entergy Mississippi $40 million 0.70% $4.4 million Entergy New Orleans $15 million 0.75% $6.2 million Entergy Texas $50 million 0.70% $5.6 million (a) The amount for Entergy Mississippi includes $0.4 million related to FTR exposure. See Note 8 to the financial statements herein for discussion of FTRs. 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 March 31, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee entered into 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 0.25% of the undrawn commitment amount. As of March 31, 2016 , $61 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the three months ended March 31, 2016 was 2.20% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also entered into 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 March 31, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of March 31, 2016 that would most likely apply to outstanding borrowings under the facility was 2.18% 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 March 31, 2016 : Company Expiration Date (a) Amount of Facility Weighted Average Interest Rate on Borrowings (b) Amount Outstanding as of March 31, 2016 (Dollars in Millions) Entergy Arkansas VIE June 2016 $85 n/a $— Entergy Louisiana River Bend VIE June 2016 $100 n/a $— Entergy Louisiana Waterford VIE June 2016 $90 1.86% $77.5 (c) System Energy VIE June 2016 $125 2.01% $111 (c) (a) Prior to expiration, the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy each plan to renew its credit facility. (b) 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. (c) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Louisiana VIEs and 0.125% of the undrawn commitment amount for the Entergy Arkansas 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 March 31, 2016 as follows: Company Description Amount Entergy Arkansas VIE 3.23% Series J due July 2016 $55 million 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 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 Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union purchase. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. 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 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 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 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 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 held in trust as of March 31, 2016 and were applied in April 2016 to the refunding of $198.68 million of outstanding series of 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. (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 Union Power Station. See Note 13 to the financial statements for discussion of the Union purchase. (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. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,296,872 $14,811,845 Entergy Arkansas $2,777,649 $2,726,079 Entergy Louisiana $5,620,234 $5,967,996 Entergy Mississippi $1,045,430 $1,100,469 Entergy New Orleans $449,892 $443,145 Entergy Texas $1,552,741 $1,702,601 System Energy $572,742 $550,080 (a) The values exclude lease obligations of $56 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. 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 2020. 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 0.275% 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 three months ended March 31, 2016 was 2.35% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $616 $7 $2,877 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 March 31, 2016 , Entergy Corporation had $578 million of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2016 was 1.14% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2016 Letters of Credit Outstanding as of March 31, 2016 Entergy Arkansas April 2016 $20 million (b) 1.93% $— $— Entergy Arkansas August 2020 $150 million (c) 1.68% $— $— Entergy Louisiana August 2020 $350 million (d) 1.68% $— $3.1 million Entergy Mississippi May 2016 $37.5 million (e) 1.93% $— $— Entergy Mississippi May 2016 $35 million (e) 1.93% $— $— Entergy Mississippi May 2016 $20 million (e) 1.93% $— $— Entergy Mississippi May 2016 $10 million (e) 1.93% $— $— Entergy New Orleans November 2018 $25 million 2.18% $— $— Entergy Texas August 2020 $150 million (f) 1.93% $— $1.3 million (a) The interest rate is the rate as of March 31, 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. The credit facility expired in April 2016. Entergy Arkansas plans to renew the credit facility. (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. Entergy Mississippi expects to renew its credit facilities prior to expiration. (f) 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 0.125% 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 March 31, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $7.0 million Entergy Mississippi $40 million 0.70% $4.4 million Entergy New Orleans $15 million 0.75% $6.2 million Entergy Texas $50 million 0.70% $5.6 million (a) The amount for Entergy Mississippi includes $0.4 million related to FTR exposure. See Note 8 to the financial statements herein for discussion of FTRs. 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 March 31, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee entered into 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 0.25% of the undrawn commitment amount. As of March 31, 2016 , $61 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the three months ended March 31, 2016 was 2.20% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also entered into 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 March 31, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of March 31, 2016 that would most likely apply to outstanding borrowings under the facility was 2.18% 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 March 31, 2016 : Company Expiration Date (a) Amount of Facility Weighted Average Interest Rate on Borrowings (b) Amount Outstanding as of March 31, 2016 (Dollars in Millions) Entergy Arkansas VIE June 2016 $85 n/a $— Entergy Louisiana River Bend VIE June 2016 $100 n/a $— Entergy Louisiana Waterford VIE June 2016 $90 1.86% $77.5 (c) System Energy VIE June 2016 $125 2.01% $111 (c) (a) Prior to expiration, the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy each plan to renew its credit facility. (b) 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. (c) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Louisiana VIEs and 0.125% of the undrawn commitment amount for the Entergy Arkansas 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 March 31, 2016 as follows: Company Description Amount Entergy Arkansas VIE 3.23% Series J due July 2016 $55 million 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 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 Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union purchase. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. 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 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 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 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 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 held in trust as of March 31, 2016 and were applied in April 2016 to the refunding of $198.68 million of outstanding series of 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. (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 Union Power Station. See Note 13 to the financial statements for discussion of the Union purchase. (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. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,296,872 $14,811,845 Entergy Arkansas $2,777,649 $2,726,079 Entergy Louisiana $5,620,234 $5,967,996 Entergy Mississippi $1,045,430 $1,100,469 Entergy New Orleans $449,892 $443,145 Entergy Texas $1,552,741 $1,702,601 System Energy $572,742 $550,080 (a) The values exclude lease obligations of $56 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. 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 2020. 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 0.275% 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 three months ended March 31, 2016 was 2.35% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $616 $7 $2,877 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 March 31, 2016 , Entergy Corporation had $578 million of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2016 was 1.14% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2016 Letters of Credit Outstanding as of March 31, 2016 Entergy Arkansas April 2016 $20 million (b) 1.93% $— $— Entergy Arkansas August 2020 $150 million (c) 1.68% $— $— Entergy Louisiana August 2020 $350 million (d) 1.68% $— $3.1 million Entergy Mississippi May 2016 $37.5 million (e) 1.93% $— $— Entergy Mississippi May 2016 $35 million (e) 1.93% $— $— Entergy Mississippi May 2016 $20 million (e) 1.93% $— $— Entergy Mississippi May 2016 $10 million (e) 1.93% $— $— Entergy New Orleans November 2018 $25 million 2.18% $— $— Entergy Texas August 2020 $150 million (f) 1.93% $— $1.3 million (a) The interest rate is the rate as of March 31, 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. The credit facility expired in April 2016. Entergy Arkansas plans to renew the credit facility. (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. Entergy Mississippi expects to renew its credit facilities prior to expiration. (f) 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 0.125% 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 March 31, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $7.0 million Entergy Mississippi $40 million 0.70% $4.4 million Entergy New Orleans $15 million 0.75% $6.2 million Entergy Texas $50 million 0.70% $5.6 million (a) The amount for Entergy Mississippi includes $0.4 million related to FTR exposure. See Note 8 to the financial statements herein for discussion of FTRs. 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 March 31, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee entered into 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 0.25% of the undrawn commitment amount. As of March 31, 2016 , $61 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the three months ended March 31, 2016 was 2.20% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also entered into 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 March 31, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of March 31, 2016 that would most likely apply to outstanding borrowings under the facility was 2.18% 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 March 31, 2016 : Company Expiration Date (a) Amount of Facility Weighted Average Interest Rate on Borrowings (b) Amount Outstanding as of March 31, 2016 (Dollars in Millions) Entergy Arkansas VIE June 2016 $85 n/a $— Entergy Louisiana River Bend VIE June 2016 $100 n/a $— Entergy Louisiana Waterford VIE June 2016 $90 1.86% $77.5 (c) System Energy VIE June 2016 $125 2.01% $111 (c) (a) Prior to expiration, the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy each plan to renew its credit facility. (b) 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. (c) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Louisiana VIEs and 0.125% of the undrawn commitment amount for the Entergy Arkansas 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 March 31, 2016 as follows: Company Description Amount Entergy Arkansas VIE 3.23% Series J due July 2016 $55 million 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 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 Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union purchase. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. 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 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 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 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 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 held in trust as of March 31, 2016 and were applied in April 2016 to the refunding of $198.68 million of outstanding series of 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. (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 Union Power Station. See Note 13 to the financial statements for discussion of the Union purchase. (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. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,296,872 $14,811,845 Entergy Arkansas $2,777,649 $2,726,079 Entergy Louisiana $5,620,234 $5,967,996 Entergy Mississippi $1,045,430 $1,100,469 Entergy New Orleans $449,892 $443,145 Entergy Texas $1,552,741 $1,702,601 System Energy $572,742 $550,080 (a) The values exclude lease obligations of $56 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. 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 2020. 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 0.275% 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 three months ended March 31, 2016 was 2.35% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $616 $7 $2,877 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 March 31, 2016 , Entergy Corporation had $578 million of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2016 was 1.14% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2016 Letters of Credit Outstanding as of March 31, 2016 Entergy Arkansas April 2016 $20 million (b) 1.93% $— $— Entergy Arkansas August 2020 $150 million (c) 1.68% $— $— Entergy Louisiana August 2020 $350 million (d) 1.68% $— $3.1 million Entergy Mississippi May 2016 $37.5 million (e) 1.93% $— $— Entergy Mississippi May 2016 $35 million (e) 1.93% $— $— Entergy Mississippi May 2016 $20 million (e) 1.93% $— $— Entergy Mississippi May 2016 $10 million (e) 1.93% $— $— Entergy New Orleans November 2018 $25 million 2.18% $— $— Entergy Texas August 2020 $150 million (f) 1.93% $— $1.3 million (a) The interest rate is the rate as of March 31, 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. The credit facility expired in April 2016. Entergy Arkansas plans to renew the credit facility. (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. Entergy Mississippi expects to renew its credit facilities prior to expiration. (f) 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 0.125% 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 March 31, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $7.0 million Entergy Mississippi $40 million 0.70% $4.4 million Entergy New Orleans $15 million 0.75% $6.2 million Entergy Texas $50 million 0.70% $5.6 million (a) The amount for Entergy Mississippi includes $0.4 million related to FTR exposure. See Note 8 to the financial statements herein for discussion of FTRs. 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 March 31, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee entered into 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 0.25% of the undrawn commitment amount. As of March 31, 2016 , $61 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the three months ended March 31, 2016 was 2.20% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also entered into 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 March 31, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of March 31, 2016 that would most likely apply to outstanding borrowings under the facility was 2.18% 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 March 31, 2016 : Company Expiration Date (a) Amount of Facility Weighted Average Interest Rate on Borrowings (b) Amount Outstanding as of March 31, 2016 (Dollars in Millions) Entergy Arkansas VIE June 2016 $85 n/a $— Entergy Louisiana River Bend VIE June 2016 $100 n/a $— Entergy Louisiana Waterford VIE June 2016 $90 1.86% $77.5 (c) System Energy VIE June 2016 $125 2.01% $111 (c) (a) Prior to expiration, the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy each plan to renew its credit facility. (b) 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. (c) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Louisiana VIEs and 0.125% of the undrawn commitment amount for the Entergy Arkansas 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 March 31, 2016 as follows: Company Description Amount Entergy Arkansas VIE 3.23% Series J due July 2016 $55 million 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 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 Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union purchase. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. 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 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 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 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 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 held in trust as of March 31, 2016 and were applied in April 2016 to the refunding of $198.68 million of outstanding series of 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. (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 Union Power Station. See Note 13 to the financial statements for discussion of the Union purchase. (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. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,296,872 $14,811,845 Entergy Arkansas $2,777,649 $2,726,079 Entergy Louisiana $5,620,234 $5,967,996 Entergy Mississippi $1,045,430 $1,100,469 Entergy New Orleans $449,892 $443,145 Entergy Texas $1,552,741 $1,702,601 System Energy $572,742 $550,080 (a) The values exclude lease obligations of $56 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. 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	3 Months Ended
	Mar. 31, 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 March 31, 2016 , there were options on 7,562,576 shares of common stock outstanding with a weighted-average exercise price of $84.06 . 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 March 31, 2016 . Because Entergy’s stock price at March 31, 2016 was less than the weighted average exercise price, the aggregate intrinsic value of the stock options outstanding as of March 31, 2016 was zero. The intrinsic value of all “in the money” stock options was $30.5 million as of March 31, 2016 . The following table includes financial information for outstanding stock options for the three months ended March 31, 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 $0.4 $0.4 Compensation cost capitalized as part of fixed assets and inventory $0.2 $0.2 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 March 31, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $8.4 $8.1 Tax benefit recognized in Entergy’s net income $3.2 $3.1 Compensation cost capitalized as part of fixed assets and inventory $1.8 $1.5

Retirement And Other Postretire

Retirement And Other Postretirement Benefits	3 Months Ended
	Mar. 31, 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 first 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 Special termination benefit — 76 Net pension costs $52,942 $80,248 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 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 $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 Non-Qualified Net Pension Cost Entergy recognized $4.3 million and $4.5 million in pension cost for its non-qualified pension plans in the first quarters of 2016 and 2015 , respectively. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the first quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost first quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost first quarter 2015 $113 $68 $59 $16 $149 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the first 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 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 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 $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 1,064 731 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,913 ($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 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 first quarters of 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($113 ) $7,355 Amortization of loss (12,482 ) (2,063 ) (630 ) (15,175 ) ($12,752 ) $5,675 ($743 ) ($7,820 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (731 ) (2 ) (1,569 ) ($836 ) $1,216 ($2 ) $378 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($107 ) $5,986 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($659 ) ($11,602 ) Entergy Louisiana Amortization of prior service credit $— $1,867 $— $1,867 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($5 ) ($668 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of March 31, 2016 , Entergy had contributed $88.2 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 $82,831 $83,909 $19,913 $10,694 $15,770 $20,206 Pension contributions made through March 2016 $19,494 $20,195 $4,946 $2,434 $3,798 $4,613 Remaining estimated pension contributions to be made in 2016 $63,337 $63,714 $14,967 $8,260 $11,972 $15,593
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 first 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 Special termination benefit — 76 Net pension costs $52,942 $80,248 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 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 $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 Non-Qualified Net Pension Cost Entergy recognized $4.3 million and $4.5 million in pension cost for its non-qualified pension plans in the first quarters of 2016 and 2015 , respectively. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the first quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost first quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost first quarter 2015 $113 $68 $59 $16 $149 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the first 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 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 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 $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 1,064 731 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,913 ($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 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 first quarters of 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($113 ) $7,355 Amortization of loss (12,482 ) (2,063 ) (630 ) (15,175 ) ($12,752 ) $5,675 ($743 ) ($7,820 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (731 ) (2 ) (1,569 ) ($836 ) $1,216 ($2 ) $378 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($107 ) $5,986 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($659 ) ($11,602 ) Entergy Louisiana Amortization of prior service credit $— $1,867 $— $1,867 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($5 ) ($668 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of March 31, 2016 , Entergy had contributed $88.2 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 $82,831 $83,909 $19,913 $10,694 $15,770 $20,206 Pension contributions made through March 2016 $19,494 $20,195 $4,946 $2,434 $3,798 $4,613 Remaining estimated pension contributions to be made in 2016 $63,337 $63,714 $14,967 $8,260 $11,972 $15,593
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 first 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 Special termination benefit — 76 Net pension costs $52,942 $80,248 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 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 $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 Non-Qualified Net Pension Cost Entergy recognized $4.3 million and $4.5 million in pension cost for its non-qualified pension plans in the first quarters of 2016 and 2015 , respectively. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the first quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost first quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost first quarter 2015 $113 $68 $59 $16 $149 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the first 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 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 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 $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 1,064 731 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,913 ($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 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 first quarters of 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($113 ) $7,355 Amortization of loss (12,482 ) (2,063 ) (630 ) (15,175 ) ($12,752 ) $5,675 ($743 ) ($7,820 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (731 ) (2 ) (1,569 ) ($836 ) $1,216 ($2 ) $378 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($107 ) $5,986 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($659 ) ($11,602 ) Entergy Louisiana Amortization of prior service credit $— $1,867 $— $1,867 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($5 ) ($668 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of March 31, 2016 , Entergy had contributed $88.2 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 $82,831 $83,909 $19,913 $10,694 $15,770 $20,206 Pension contributions made through March 2016 $19,494 $20,195 $4,946 $2,434 $3,798 $4,613 Remaining estimated pension contributions to be made in 2016 $63,337 $63,714 $14,967 $8,260 $11,972 $15,593
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 first 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 Special termination benefit — 76 Net pension costs $52,942 $80,248 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 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 $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 Non-Qualified Net Pension Cost Entergy recognized $4.3 million and $4.5 million in pension cost for its non-qualified pension plans in the first quarters of 2016 and 2015 , respectively. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the first quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost first quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost first quarter 2015 $113 $68 $59 $16 $149 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the first 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 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 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 $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 1,064 731 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,913 ($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 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 first quarters of 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($113 ) $7,355 Amortization of loss (12,482 ) (2,063 ) (630 ) (15,175 ) ($12,752 ) $5,675 ($743 ) ($7,820 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (731 ) (2 ) (1,569 ) ($836 ) $1,216 ($2 ) $378 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($107 ) $5,986 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($659 ) ($11,602 ) Entergy Louisiana Amortization of prior service credit $— $1,867 $— $1,867 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($5 ) ($668 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of March 31, 2016 , Entergy had contributed $88.2 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 $82,831 $83,909 $19,913 $10,694 $15,770 $20,206 Pension contributions made through March 2016 $19,494 $20,195 $4,946 $2,434 $3,798 $4,613 Remaining estimated pension contributions to be made in 2016 $63,337 $63,714 $14,967 $8,260 $11,972 $15,593
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 first 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 Special termination benefit — 76 Net pension costs $52,942 $80,248 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 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 $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 Non-Qualified Net Pension Cost Entergy recognized $4.3 million and $4.5 million in pension cost for its non-qualified pension plans in the first quarters of 2016 and 2015 , respectively. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the first quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost first quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost first quarter 2015 $113 $68 $59 $16 $149 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the first 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 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 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 $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 1,064 731 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,913 ($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 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 first quarters of 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($113 ) $7,355 Amortization of loss (12,482 ) (2,063 ) (630 ) (15,175 ) ($12,752 ) $5,675 ($743 ) ($7,820 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (731 ) (2 ) (1,569 ) ($836 ) $1,216 ($2 ) $378 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($107 ) $5,986 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($659 ) ($11,602 ) Entergy Louisiana Amortization of prior service credit $— $1,867 $— $1,867 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($5 ) ($668 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of March 31, 2016 , Entergy had contributed $88.2 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 $82,831 $83,909 $19,913 $10,694 $15,770 $20,206 Pension contributions made through March 2016 $19,494 $20,195 $4,946 $2,434 $3,798 $4,613 Remaining estimated pension contributions to be made in 2016 $63,337 $63,714 $14,967 $8,260 $11,972 $15,593
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 first 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 Special termination benefit — 76 Net pension costs $52,942 $80,248 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 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 $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 Non-Qualified Net Pension Cost Entergy recognized $4.3 million and $4.5 million in pension cost for its non-qualified pension plans in the first quarters of 2016 and 2015 , respectively. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the first quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost first quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost first quarter 2015 $113 $68 $59 $16 $149 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the first 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 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 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 $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 1,064 731 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,913 ($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 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 first quarters of 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($113 ) $7,355 Amortization of loss (12,482 ) (2,063 ) (630 ) (15,175 ) ($12,752 ) $5,675 ($743 ) ($7,820 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (731 ) (2 ) (1,569 ) ($836 ) $1,216 ($2 ) $378 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($107 ) $5,986 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($659 ) ($11,602 ) Entergy Louisiana Amortization of prior service credit $— $1,867 $— $1,867 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($5 ) ($668 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of March 31, 2016 , Entergy had contributed $88.2 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 $82,831 $83,909 $19,913 $10,694 $15,770 $20,206 Pension contributions made through March 2016 $19,494 $20,195 $4,946 $2,434 $3,798 $4,613 Remaining estimated pension contributions to be made in 2016 $63,337 $63,714 $14,967 $8,260 $11,972 $15,593
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 first 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 Special termination benefit — 76 Net pension costs $52,942 $80,248 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 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 $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 Non-Qualified Net Pension Cost Entergy recognized $4.3 million and $4.5 million in pension cost for its non-qualified pension plans in the first quarters of 2016 and 2015 , respectively. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the first quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost first quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost first quarter 2015 $113 $68 $59 $16 $149 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the first 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 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 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 $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 1,064 731 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,913 ($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 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 first quarters of 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($113 ) $7,355 Amortization of loss (12,482 ) (2,063 ) (630 ) (15,175 ) ($12,752 ) $5,675 ($743 ) ($7,820 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (731 ) (2 ) (1,569 ) ($836 ) $1,216 ($2 ) $378 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($107 ) $5,986 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($659 ) ($11,602 ) Entergy Louisiana Amortization of prior service credit $— $1,867 $— $1,867 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($5 ) ($668 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of March 31, 2016 , Entergy had contributed $88.2 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 $82,831 $83,909 $19,913 $10,694 $15,770 $20,206 Pension contributions made through March 2016 $19,494 $20,195 $4,946 $2,434 $3,798 $4,613 Remaining estimated pension contributions to be made in 2016 $63,337 $63,714 $14,967 $8,260 $11,972 $15,593

Business Segment Information

Business Segment Information	3 Months Ended
	Mar. 31, 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 March 31, 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 first quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,087,793 $522,079 $— ($20 ) $2,609,852 Income taxes $107,836 $52,314 ($20,205 ) $— $139,945 Consolidated net income (loss) $199,651 $79,557 ($12,067 ) ($31,899 ) $235,242 2015 Operating revenues $2,277,510 $642,590 $— ($10 ) $2,920,090 Income taxes $91,251 $70,190 ($10,970 ) $— $150,471 Consolidated net income (loss) $227,750 $123,432 ($16,354 ) ($31,899 ) $302,929 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 March 31, 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 first quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,087,793 $522,079 $— ($20 ) $2,609,852 Income taxes $107,836 $52,314 ($20,205 ) $— $139,945 Consolidated net income (loss) $199,651 $79,557 ($12,067 ) ($31,899 ) $235,242 2015 Operating revenues $2,277,510 $642,590 $— ($10 ) $2,920,090 Income taxes $91,251 $70,190 ($10,970 ) $— $150,471 Consolidated net income (loss) $227,750 $123,432 ($16,354 ) ($31,899 ) $302,929 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 March 31, 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 first quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,087,793 $522,079 $— ($20 ) $2,609,852 Income taxes $107,836 $52,314 ($20,205 ) $— $139,945 Consolidated net income (loss) $199,651 $79,557 ($12,067 ) ($31,899 ) $235,242 2015 Operating revenues $2,277,510 $642,590 $— ($10 ) $2,920,090 Income taxes $91,251 $70,190 ($10,970 ) $— $150,471 Consolidated net income (loss) $227,750 $123,432 ($16,354 ) ($31,899 ) $302,929 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 March 31, 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 first quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,087,793 $522,079 $— ($20 ) $2,609,852 Income taxes $107,836 $52,314 ($20,205 ) $— $139,945 Consolidated net income (loss) $199,651 $79,557 ($12,067 ) ($31,899 ) $235,242 2015 Operating revenues $2,277,510 $642,590 $— ($10 ) $2,920,090 Income taxes $91,251 $70,190 ($10,970 ) $— $150,471 Consolidated net income (loss) $227,750 $123,432 ($16,354 ) ($31,899 ) $302,929 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 March 31, 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 first quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,087,793 $522,079 $— ($20 ) $2,609,852 Income taxes $107,836 $52,314 ($20,205 ) $— $139,945 Consolidated net income (loss) $199,651 $79,557 ($12,067 ) ($31,899 ) $235,242 2015 Operating revenues $2,277,510 $642,590 $— ($10 ) $2,920,090 Income taxes $91,251 $70,190 ($10,970 ) $— $150,471 Consolidated net income (loss) $227,750 $123,432 ($16,354 ) ($31,899 ) $302,929 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 March 31, 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 first quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,087,793 $522,079 $— ($20 ) $2,609,852 Income taxes $107,836 $52,314 ($20,205 ) $— $139,945 Consolidated net income (loss) $199,651 $79,557 ($12,067 ) ($31,899 ) $235,242 2015 Operating revenues $2,277,510 $642,590 $— ($10 ) $2,920,090 Income taxes $91,251 $70,190 ($10,970 ) $— $150,471 Consolidated net income (loss) $227,750 $123,432 ($16,354 ) ($31,899 ) $302,929 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 March 31, 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 first quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,087,793 $522,079 $— ($20 ) $2,609,852 Income taxes $107,836 $52,314 ($20,205 ) $— $139,945 Consolidated net income (loss) $199,651 $79,557 ($12,067 ) ($31,899 ) $235,242 2015 Operating revenues $2,277,510 $642,590 $— ($10 ) $2,920,090 Income taxes $91,251 $70,190 ($10,970 ) $— $150,471 Consolidated net income (loss) $227,750 $123,432 ($16,354 ) ($31,899 ) $302,929 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	3 Months Ended
	Mar. 31, 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 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 March 31, 2016 is approximately 2 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 88% for the remainder of 2016 , of which approximately 60% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2016 is 25 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 when the current market prices exceed the contracted power prices. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of March 31, 2016 , there were no derivative contracts with counterparties in a liability position. Letters of credit in the amount of $66 million were required to be posted by its counterparties to the Entergy subsidiary as of March 31, 2016. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). In addition to the corporate guarantee, $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 March 31, 2016 is 57,500,000 MMBtu for Entergy, including 46,330,000 MMBtu for Entergy Louisiana and 11,170,000 MMBtu for Entergy Mississippi. 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 2015, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2015 through May 31, 2016. 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 March 31, 2016 is 18,305 GWh for Entergy, including 3,894 GWh for Entergy Arkansas, 8,385 GWh for Entergy Louisiana, 2,436 GWh for Entergy Mississippi, 1,398 GWh for Entergy New Orleans, and 2,086 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. As of March 31, 2016 , letters of credit posted with MISO covered the FTR exposure for Entergy Mississippi. No cash collateral was required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities. As of December 31, 2015, no cash or letters of credit were required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 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) $120 ($26) $94 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($1) $19 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) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $94 ($24) $70 Entergy Wholesale Commodities FTRs Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $49 ($49) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 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 $9 million posted and $68 million held as of December 31, 2015. There was no cash collateral required to be posted as of March 31, 2016. Also excludes letters of credit in the amount of $0.4 million posted and $66 million held as of March 31, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended March 31, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $139 Competitive businesses operating revenues $154 2015 Electricity swaps and options ($32) Competitive businesses operating revenues $14 (a) Before taxes of $54 million and $5 million for the three months ended March 31, 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 March 31, 2016 and 2015 was ($1) million and ($1) million , respectively. Based on market prices as of March 31, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $152 million . Approximately $134 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 March 31, 2016 and 2015 are as follows: Instrument Amount of gain (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) ($24) FTRs $— Purchased power expense (b) $21 Electricity swaps and options de-designated as hedged items $25 Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($19) FTRs $— Purchased power expense (b) $33 Electricity swaps and options de-designated as hedged items $4 Competitive business operating revenues ($34) (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. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $3.7 Entergy Arkansas FTRs Prepayments and other $3.3 Entergy Louisiana FTRs Prepayments and other $0.9 Entergy Mississippi FTRs Prepayments and other $0.6 Entergy New Orleans FTRs Prepayments and other $0.9 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.6 Entergy Louisiana Natural gas swaps Other current liabilities $1.8 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) Excludes letters of credit in the amount of $0.4 million posted by Entergy Mississippi as of March 31, 2016. No cash collateral was required to be posted as of March 31, 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 March 31, 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 ($19.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.1) (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 $7.8 (b) Entergy Arkansas FTRs Purchased power expense $10.5 (b) Entergy Louisiana FTRs Purchased power expense $0.8 (b) Entergy Mississippi FTRs Purchased power expense $0.5 (b) Entergy New Orleans FTRs Purchased power expense $1.5 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.0) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (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 $15.1 (b) Entergy Arkansas FTRs Purchased power expense $14.5 (b) Entergy Louisiana FTRs Purchased power expense $3.3 (b) Entergy Mississippi FTRs Purchased power expense $1.6 (b) Entergy New Orleans FTRs Purchased power expense ($1.4) (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 Entergy Wholesale Commodities Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Entergy Wholesale Commodities 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 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 Entergy Wholesale Commodities 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, Entergy Wholesale Commodities Risk Control group calculates the mark-to-market for electricity swaps and options. Entergy Wholesale Commodities 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 effects are calculated for this analysis. This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of FTRs are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Entergy Wholesale Commodities Risk Control group for the unregulated business and by the System Planning and Operations Risk Control group for the Utility operating companies. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Risk Control groups report to the Vice President and Treasurer. The Accounting Policy group reports to the Chief Accounting Officer. 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 March 31, 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 $1,010 $— $— $1,010 Funds held on deposit 197 — — 197 Decommissioning trust funds (a): Equity securities 446 — — 446 Debt securities 1,060 1,189 — 2,249 Common trusts (b) 2,757 Power contracts — — 183 183 Securitization recovery trust account 52 — — 52 Escrow accounts 454 — — 454 FTRs — — 9 9 $3,219 $1,189 $192 $7,357 Liabilities: Gas hedge contracts $9 $— $— $9 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 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value (NAV) 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 NAV 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 classifie
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 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 March 31, 2016 is approximately 2 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 88% for the remainder of 2016 , of which approximately 60% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2016 is 25 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 when the current market prices exceed the contracted power prices. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of March 31, 2016 , there were no derivative contracts with counterparties in a liability position. Letters of credit in the amount of $66 million were required to be posted by its counterparties to the Entergy subsidiary as of March 31, 2016. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). In addition to the corporate guarantee, $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 March 31, 2016 is 57,500,000 MMBtu for Entergy, including 46,330,000 MMBtu for Entergy Louisiana and 11,170,000 MMBtu for Entergy Mississippi. 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 2015, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2015 through May 31, 2016. 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 March 31, 2016 is 18,305 GWh for Entergy, including 3,894 GWh for Entergy Arkansas, 8,385 GWh for Entergy Louisiana, 2,436 GWh for Entergy Mississippi, 1,398 GWh for Entergy New Orleans, and 2,086 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. As of March 31, 2016 , letters of credit posted with MISO covered the FTR exposure for Entergy Mississippi. No cash collateral was required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities. As of December 31, 2015, no cash or letters of credit were required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 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) $120 ($26) $94 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($1) $19 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) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $94 ($24) $70 Entergy Wholesale Commodities FTRs Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $49 ($49) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 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 $9 million posted and $68 million held as of December 31, 2015. There was no cash collateral required to be posted as of March 31, 2016. Also excludes letters of credit in the amount of $0.4 million posted and $66 million held as of March 31, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended March 31, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $139 Competitive businesses operating revenues $154 2015 Electricity swaps and options ($32) Competitive businesses operating revenues $14 (a) Before taxes of $54 million and $5 million for the three months ended March 31, 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 March 31, 2016 and 2015 was ($1) million and ($1) million , respectively. Based on market prices as of March 31, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $152 million . Approximately $134 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 March 31, 2016 and 2015 are as follows: Instrument Amount of gain (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) ($24) FTRs $— Purchased power expense (b) $21 Electricity swaps and options de-designated as hedged items $25 Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($19) FTRs $— Purchased power expense (b) $33 Electricity swaps and options de-designated as hedged items $4 Competitive business operating revenues ($34) (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. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $3.7 Entergy Arkansas FTRs Prepayments and other $3.3 Entergy Louisiana FTRs Prepayments and other $0.9 Entergy Mississippi FTRs Prepayments and other $0.6 Entergy New Orleans FTRs Prepayments and other $0.9 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.6 Entergy Louisiana Natural gas swaps Other current liabilities $1.8 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) Excludes letters of credit in the amount of $0.4 million posted by Entergy Mississippi as of March 31, 2016. No cash collateral was required to be posted as of March 31, 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 March 31, 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 ($19.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.1) (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 $7.8 (b) Entergy Arkansas FTRs Purchased power expense $10.5 (b) Entergy Louisiana FTRs Purchased power expense $0.8 (b) Entergy Mississippi FTRs Purchased power expense $0.5 (b) Entergy New Orleans FTRs Purchased power expense $1.5 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.0) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (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 $15.1 (b) Entergy Arkansas FTRs Purchased power expense $14.5 (b) Entergy Louisiana FTRs Purchased power expense $3.3 (b) Entergy Mississippi FTRs Purchased power expense $1.6 (b) Entergy New Orleans FTRs Purchased power expense ($1.4) (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 Entergy Wholesale Commodities Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Entergy Wholesale Commodities 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 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 Entergy Wholesale Commodities 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, Entergy Wholesale Commodities Risk Control group calculates the mark-to-market for electricity swaps and options. Entergy Wholesale Commodities 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 effects are calculated for this analysis. This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of FTRs are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Entergy Wholesale Commodities Risk Control group for the unregulated business and by the System Planning and Operations Risk Control group for the Utility operating companies. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Risk Control groups report to the Vice President and Treasurer. The Accounting Policy group reports to the Chief Accounting Officer. 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 March 31, 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 $1,010 $— $— $1,010 Funds held on deposit 197 — — 197 Decommissioning trust funds (a): Equity securities 446 — — 446 Debt securities 1,060 1,189 — 2,249 Common trusts (b) 2,757 Power contracts — — 183 183 Securitization recovery trust account 52 — — 52 Escrow accounts 454 — — 454 FTRs — — 9 9 $3,219 $1,189 $192 $7,357 Liabilities: Gas hedge contracts $9 $— $— $9 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 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value (NAV) 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 NAV 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 classifie
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 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 March 31, 2016 is approximately 2 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 88% for the remainder of 2016 , of which approximately 60% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2016 is 25 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 when the current market prices exceed the contracted power prices. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of March 31, 2016 , there were no derivative contracts with counterparties in a liability position. Letters of credit in the amount of $66 million were required to be posted by its counterparties to the Entergy subsidiary as of March 31, 2016. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). In addition to the corporate guarantee, $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 March 31, 2016 is 57,500,000 MMBtu for Entergy, including 46,330,000 MMBtu for Entergy Louisiana and 11,170,000 MMBtu for Entergy Mississippi. 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 2015, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2015 through May 31, 2016. 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 March 31, 2016 is 18,305 GWh for Entergy, including 3,894 GWh for Entergy Arkansas, 8,385 GWh for Entergy Louisiana, 2,436 GWh for Entergy Mississippi, 1,398 GWh for Entergy New Orleans, and 2,086 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. As of March 31, 2016 , letters of credit posted with MISO covered the FTR exposure for Entergy Mississippi. No cash collateral was required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities. As of December 31, 2015, no cash or letters of credit were required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 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) $120 ($26) $94 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($1) $19 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) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $94 ($24) $70 Entergy Wholesale Commodities FTRs Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $49 ($49) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 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 $9 million posted and $68 million held as of December 31, 2015. There was no cash collateral required to be posted as of March 31, 2016. Also excludes letters of credit in the amount of $0.4 million posted and $66 million held as of March 31, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended March 31, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $139 Competitive businesses operating revenues $154 2015 Electricity swaps and options ($32) Competitive businesses operating revenues $14 (a) Before taxes of $54 million and $5 million for the three months ended March 31, 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 March 31, 2016 and 2015 was ($1) million and ($1) million , respectively. Based on market prices as of March 31, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $152 million . Approximately $134 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 March 31, 2016 and 2015 are as follows: Instrument Amount of gain (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) ($24) FTRs $— Purchased power expense (b) $21 Electricity swaps and options de-designated as hedged items $25 Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($19) FTRs $— Purchased power expense (b) $33 Electricity swaps and options de-designated as hedged items $4 Competitive business operating revenues ($34) (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. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $3.7 Entergy Arkansas FTRs Prepayments and other $3.3 Entergy Louisiana FTRs Prepayments and other $0.9 Entergy Mississippi FTRs Prepayments and other $0.6 Entergy New Orleans FTRs Prepayments and other $0.9 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.6 Entergy Louisiana Natural gas swaps Other current liabilities $1.8 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) Excludes letters of credit in the amount of $0.4 million posted by Entergy Mississippi as of March 31, 2016. No cash collateral was required to be posted as of March 31, 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 March 31, 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 ($19.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.1) (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 $7.8 (b) Entergy Arkansas FTRs Purchased power expense $10.5 (b) Entergy Louisiana FTRs Purchased power expense $0.8 (b) Entergy Mississippi FTRs Purchased power expense $0.5 (b) Entergy New Orleans FTRs Purchased power expense $1.5 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.0) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (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 $15.1 (b) Entergy Arkansas FTRs Purchased power expense $14.5 (b) Entergy Louisiana FTRs Purchased power expense $3.3 (b) Entergy Mississippi FTRs Purchased power expense $1.6 (b) Entergy New Orleans FTRs Purchased power expense ($1.4) (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 Entergy Wholesale Commodities Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Entergy Wholesale Commodities 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 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 Entergy Wholesale Commodities 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, Entergy Wholesale Commodities Risk Control group calculates the mark-to-market for electricity swaps and options. Entergy Wholesale Commodities 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 effects are calculated for this analysis. This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of FTRs are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Entergy Wholesale Commodities Risk Control group for the unregulated business and by the System Planning and Operations Risk Control group for the Utility operating companies. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Risk Control groups report to the Vice President and Treasurer. The Accounting Policy group reports to the Chief Accounting Officer. 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 March 31, 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 $1,010 $— $— $1,010 Funds held on deposit 197 — — 197 Decommissioning trust funds (a): Equity securities 446 — — 446 Debt securities 1,060 1,189 — 2,249 Common trusts (b) 2,757 Power contracts — — 183 183 Securitization recovery trust account 52 — — 52 Escrow accounts 454 — — 454 FTRs — — 9 9 $3,219 $1,189 $192 $7,357 Liabilities: Gas hedge contracts $9 $— $— $9 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 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value (NAV) 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 NAV 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 classifie
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 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 March 31, 2016 is approximately 2 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 88% for the remainder of 2016 , of which approximately 60% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2016 is 25 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 when the current market prices exceed the contracted power prices. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of March 31, 2016 , there were no derivative contracts with counterparties in a liability position. Letters of credit in the amount of $66 million were required to be posted by its counterparties to the Entergy subsidiary as of March 31, 2016. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). In addition to the corporate guarantee, $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 March 31, 2016 is 57,500,000 MMBtu for Entergy, including 46,330,000 MMBtu for Entergy Louisiana and 11,170,000 MMBtu for Entergy Mississippi. 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 2015, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2015 through May 31, 2016. 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 March 31, 2016 is 18,305 GWh for Entergy, including 3,894 GWh for Entergy Arkansas, 8,385 GWh for Entergy Louisiana, 2,436 GWh for Entergy Mississippi, 1,398 GWh for Entergy New Orleans, and 2,086 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. As of March 31, 2016 , letters of credit posted with MISO covered the FTR exposure for Entergy Mississippi. No cash collateral was required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities. As of December 31, 2015, no cash or letters of credit were required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 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) $120 ($26) $94 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($1) $19 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) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $94 ($24) $70 Entergy Wholesale Commodities FTRs Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $49 ($49) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 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 $9 million posted and $68 million held as of December 31, 2015. There was no cash collateral required to be posted as of March 31, 2016. Also excludes letters of credit in the amount of $0.4 million posted and $66 million held as of March 31, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended March 31, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $139 Competitive businesses operating revenues $154 2015 Electricity swaps and options ($32) Competitive businesses operating revenues $14 (a) Before taxes of $54 million and $5 million for the three months ended March 31, 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 March 31, 2016 and 2015 was ($1) million and ($1) million , respectively. Based on market prices as of March 31, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $152 million . Approximately $134 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 March 31, 2016 and 2015 are as follows: Instrument Amount of gain (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) ($24) FTRs $— Purchased power expense (b) $21 Electricity swaps and options de-designated as hedged items $25 Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($19) FTRs $— Purchased power expense (b) $33 Electricity swaps and options de-designated as hedged items $4 Competitive business operating revenues ($34) (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. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $3.7 Entergy Arkansas FTRs Prepayments and other $3.3 Entergy Louisiana FTRs Prepayments and other $0.9 Entergy Mississippi FTRs Prepayments and other $0.6 Entergy New Orleans FTRs Prepayments and other $0.9 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.6 Entergy Louisiana Natural gas swaps Other current liabilities $1.8 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) Excludes letters of credit in the amount of $0.4 million posted by Entergy Mississippi as of March 31, 2016. No cash collateral was required to be posted as of March 31, 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 March 31, 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 ($19.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.1) (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 $7.8 (b) Entergy Arkansas FTRs Purchased power expense $10.5 (b) Entergy Louisiana FTRs Purchased power expense $0.8 (b) Entergy Mississippi FTRs Purchased power expense $0.5 (b) Entergy New Orleans FTRs Purchased power expense $1.5 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.0) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (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 $15.1 (b) Entergy Arkansas FTRs Purchased power expense $14.5 (b) Entergy Louisiana FTRs Purchased power expense $3.3 (b) Entergy Mississippi FTRs Purchased power expense $1.6 (b) Entergy New Orleans FTRs Purchased power expense ($1.4) (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 Entergy Wholesale Commodities Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Entergy Wholesale Commodities 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 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 Entergy Wholesale Commodities 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, Entergy Wholesale Commodities Risk Control group calculates the mark-to-market for electricity swaps and options. Entergy Wholesale Commodities 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 effects are calculated for this analysis. This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of FTRs are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Entergy Wholesale Commodities Risk Control group for the unregulated business and by the System Planning and Operations Risk Control group for the Utility operating companies. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Risk Control groups report to the Vice President and Treasurer. The Accounting Policy group reports to the Chief Accounting Officer. 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 March 31, 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 $1,010 $— $— $1,010 Funds held on deposit 197 — — 197 Decommissioning trust funds (a): Equity securities 446 — — 446 Debt securities 1,060 1,189 — 2,249 Common trusts (b) 2,757 Power contracts — — 183 183 Securitization recovery trust account 52 — — 52 Escrow accounts 454 — — 454 FTRs — — 9 9 $3,219 $1,189 $192 $7,357 Liabilities: Gas hedge contracts $9 $— $— $9 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 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value (NAV) 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 NAV 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 classifie
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 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 March 31, 2016 is approximately 2 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 88% for the remainder of 2016 , of which approximately 60% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2016 is 25 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 when the current market prices exceed the contracted power prices. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of March 31, 2016 , there were no derivative contracts with counterparties in a liability position. Letters of credit in the amount of $66 million were required to be posted by its counterparties to the Entergy subsidiary as of March 31, 2016. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). In addition to the corporate guarantee, $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 March 31, 2016 is 57,500,000 MMBtu for Entergy, including 46,330,000 MMBtu for Entergy Louisiana and 11,170,000 MMBtu for Entergy Mississippi. 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 2015, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2015 through May 31, 2016. 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 March 31, 2016 is 18,305 GWh for Entergy, including 3,894 GWh for Entergy Arkansas, 8,385 GWh for Entergy Louisiana, 2,436 GWh for Entergy Mississippi, 1,398 GWh for Entergy New Orleans, and 2,086 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. As of March 31, 2016 , letters of credit posted with MISO covered the FTR exposure for Entergy Mississippi. No cash collateral was required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities. As of December 31, 2015, no cash or letters of credit were required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 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) $120 ($26) $94 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($1) $19 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) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $94 ($24) $70 Entergy Wholesale Commodities FTRs Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $49 ($49) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 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 $9 million posted and $68 million held as of December 31, 2015. There was no cash collateral required to be posted as of March 31, 2016. Also excludes letters of credit in the amount of $0.4 million posted and $66 million held as of March 31, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended March 31, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $139 Competitive businesses operating revenues $154 2015 Electricity swaps and options ($32) Competitive businesses operating revenues $14 (a) Before taxes of $54 million and $5 million for the three months ended March 31, 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 March 31, 2016 and 2015 was ($1) million and ($1) million , respectively. Based on market prices as of March 31, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $152 million . Approximately $134 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 March 31, 2016 and 2015 are as follows: Instrument Amount of gain (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) ($24) FTRs $— Purchased power expense (b) $21 Electricity swaps and options de-designated as hedged items $25 Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($19) FTRs $— Purchased power expense (b) $33 Electricity swaps and options de-designated as hedged items $4 Competitive business operating revenues ($34) (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. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $3.7 Entergy Arkansas FTRs Prepayments and other $3.3 Entergy Louisiana FTRs Prepayments and other $0.9 Entergy Mississippi FTRs Prepayments and other $0.6 Entergy New Orleans FTRs Prepayments and other $0.9 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.6 Entergy Louisiana Natural gas swaps Other current liabilities $1.8 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) Excludes letters of credit in the amount of $0.4 million posted by Entergy Mississippi as of March 31, 2016. No cash collateral was required to be posted as of March 31, 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 March 31, 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 ($19.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.1) (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 $7.8 (b) Entergy Arkansas FTRs Purchased power expense $10.5 (b) Entergy Louisiana FTRs Purchased power expense $0.8 (b) Entergy Mississippi FTRs Purchased power expense $0.5 (b) Entergy New Orleans FTRs Purchased power expense $1.5 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.0) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (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 $15.1 (b) Entergy Arkansas FTRs Purchased power expense $14.5 (b) Entergy Louisiana FTRs Purchased power expense $3.3 (b) Entergy Mississippi FTRs Purchased power expense $1.6 (b) Entergy New Orleans FTRs Purchased power expense ($1.4) (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 Entergy Wholesale Commodities Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Entergy Wholesale Commodities 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 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 Entergy Wholesale Commodities 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, Entergy Wholesale Commodities Risk Control group calculates the mark-to-market for electricity swaps and options. Entergy Wholesale Commodities 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 effects are calculated for this analysis. This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of FTRs are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Entergy Wholesale Commodities Risk Control group for the unregulated business and by the System Planning and Operations Risk Control group for the Utility operating companies. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Risk Control groups report to the Vice President and Treasurer. The Accounting Policy group reports to the Chief Accounting Officer. 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 March 31, 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 $1,010 $— $— $1,010 Funds held on deposit 197 — — 197 Decommissioning trust funds (a): Equity securities 446 — — 446 Debt securities 1,060 1,189 — 2,249 Common trusts (b) 2,757 Power contracts — — 183 183 Securitization recovery trust account 52 — — 52 Escrow accounts 454 — — 454 FTRs — — 9 9 $3,219 $1,189 $192 $7,357 Liabilities: Gas hedge contracts $9 $— $— $9 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 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value (NAV) 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 NAV 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 classifie
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 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 March 31, 2016 is approximately 2 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 88% for the remainder of 2016 , of which approximately 60% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2016 is 25 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 when the current market prices exceed the contracted power prices. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of March 31, 2016 , there were no derivative contracts with counterparties in a liability position. Letters of credit in the amount of $66 million were required to be posted by its counterparties to the Entergy subsidiary as of March 31, 2016. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). In addition to the corporate guarantee, $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 March 31, 2016 is 57,500,000 MMBtu for Entergy, including 46,330,000 MMBtu for Entergy Louisiana and 11,170,000 MMBtu for Entergy Mississippi. 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 2015, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2015 through May 31, 2016. 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 March 31, 2016 is 18,305 GWh for Entergy, including 3,894 GWh for Entergy Arkansas, 8,385 GWh for Entergy Louisiana, 2,436 GWh for Entergy Mississippi, 1,398 GWh for Entergy New Orleans, and 2,086 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. As of March 31, 2016 , letters of credit posted with MISO covered the FTR exposure for Entergy Mississippi. No cash collateral was required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities. As of December 31, 2015, no cash or letters of credit were required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 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) $120 ($26) $94 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($1) $19 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) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $94 ($24) $70 Entergy Wholesale Commodities FTRs Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $49 ($49) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 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 $9 million posted and $68 million held as of December 31, 2015. There was no cash collateral required to be posted as of March 31, 2016. Also excludes letters of credit in the amount of $0.4 million posted and $66 million held as of March 31, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended March 31, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $139 Competitive businesses operating revenues $154 2015 Electricity swaps and options ($32) Competitive businesses operating revenues $14 (a) Before taxes of $54 million and $5 million for the three months ended March 31, 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 March 31, 2016 and 2015 was ($1) million and ($1) million , respectively. Based on market prices as of March 31, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $152 million . Approximately $134 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 March 31, 2016 and 2015 are as follows: Instrument Amount of gain (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) ($24) FTRs $— Purchased power expense (b) $21 Electricity swaps and options de-designated as hedged items $25 Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($19) FTRs $— Purchased power expense (b) $33 Electricity swaps and options de-designated as hedged items $4 Competitive business operating revenues ($34) (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. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $3.7 Entergy Arkansas FTRs Prepayments and other $3.3 Entergy Louisiana FTRs Prepayments and other $0.9 Entergy Mississippi FTRs Prepayments and other $0.6 Entergy New Orleans FTRs Prepayments and other $0.9 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.6 Entergy Louisiana Natural gas swaps Other current liabilities $1.8 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) Excludes letters of credit in the amount of $0.4 million posted by Entergy Mississippi as of March 31, 2016. No cash collateral was required to be posted as of March 31, 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 March 31, 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 ($19.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.1) (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 $7.8 (b) Entergy Arkansas FTRs Purchased power expense $10.5 (b) Entergy Louisiana FTRs Purchased power expense $0.8 (b) Entergy Mississippi FTRs Purchased power expense $0.5 (b) Entergy New Orleans FTRs Purchased power expense $1.5 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.0) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (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 $15.1 (b) Entergy Arkansas FTRs Purchased power expense $14.5 (b) Entergy Louisiana FTRs Purchased power expense $3.3 (b) Entergy Mississippi FTRs Purchased power expense $1.6 (b) Entergy New Orleans FTRs Purchased power expense ($1.4) (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 Entergy Wholesale Commodities Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Entergy Wholesale Commodities 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 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 Entergy Wholesale Commodities 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, Entergy Wholesale Commodities Risk Control group calculates the mark-to-market for electricity swaps and options. Entergy Wholesale Commodities 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 effects are calculated for this analysis. This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of FTRs are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Entergy Wholesale Commodities Risk Control group for the unregulated business and by the System Planning and Operations Risk Control group for the Utility operating companies. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Risk Control groups report to the Vice President and Treasurer. The Accounting Policy group reports to the Chief Accounting Officer. 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 March 31, 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 $1,010 $— $— $1,010 Funds held on deposit 197 — — 197 Decommissioning trust funds (a): Equity securities 446 — — 446 Debt securities 1,060 1,189 — 2,249 Common trusts (b) 2,757 Power contracts — — 183 183 Securitization recovery trust account 52 — — 52 Escrow accounts 454 — — 454 FTRs — — 9 9 $3,219 $1,189 $192 $7,357 Liabilities: Gas hedge contracts $9 $— $— $9 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 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value (NAV) 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 NAV 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 classifie
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 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 March 31, 2016 is approximately 2 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 88% for the remainder of 2016 , of which approximately 60% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2016 is 25 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 when the current market prices exceed the contracted power prices. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of March 31, 2016 , there were no derivative contracts with counterparties in a liability position. Letters of credit in the amount of $66 million were required to be posted by its counterparties to the Entergy subsidiary as of March 31, 2016. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). In addition to the corporate guarantee, $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 March 31, 2016 is 57,500,000 MMBtu for Entergy, including 46,330,000 MMBtu for Entergy Louisiana and 11,170,000 MMBtu for Entergy Mississippi. 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 2015, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2015 through May 31, 2016. 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 March 31, 2016 is 18,305 GWh for Entergy, including 3,894 GWh for Entergy Arkansas, 8,385 GWh for Entergy Louisiana, 2,436 GWh for Entergy Mississippi, 1,398 GWh for Entergy New Orleans, and 2,086 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. As of March 31, 2016 , letters of credit posted with MISO covered the FTR exposure for Entergy Mississippi. No cash collateral was required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities. As of December 31, 2015, no cash or letters of credit were required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities, respectively. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 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) $120 ($26) $94 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($1) $19 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) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $94 ($24) $70 Entergy Wholesale Commodities FTRs Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $49 ($49) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 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 $9 million posted and $68 million held as of December 31, 2015. There was no cash collateral required to be posted as of March 31, 2016. Also excludes letters of credit in the amount of $0.4 million posted and $66 million held as of March 31, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended March 31, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $139 Competitive businesses operating revenues $154 2015 Electricity swaps and options ($32) Competitive businesses operating revenues $14 (a) Before taxes of $54 million and $5 million for the three months ended March 31, 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 March 31, 2016 and 2015 was ($1) million and ($1) million , respectively. Based on market prices as of March 31, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $152 million . Approximately $134 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 March 31, 2016 and 2015 are as follows: Instrument Amount of gain (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) ($24) FTRs $— Purchased power expense (b) $21 Electricity swaps and options de-designated as hedged items $25 Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($19) FTRs $— Purchased power expense (b) $33 Electricity swaps and options de-designated as hedged items $4 Competitive business operating revenues ($34) (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. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $3.7 Entergy Arkansas FTRs Prepayments and other $3.3 Entergy Louisiana FTRs Prepayments and other $0.9 Entergy Mississippi FTRs Prepayments and other $0.6 Entergy New Orleans FTRs Prepayments and other $0.9 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.6 Entergy Louisiana Natural gas swaps Other current liabilities $1.8 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) Excludes letters of credit in the amount of $0.4 million posted by Entergy Mississippi as of March 31, 2016. No cash collateral was required to be posted as of March 31, 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 March 31, 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 ($19.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.1) (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 $7.8 (b) Entergy Arkansas FTRs Purchased power expense $10.5 (b) Entergy Louisiana FTRs Purchased power expense $0.8 (b) Entergy Mississippi FTRs Purchased power expense $0.5 (b) Entergy New Orleans FTRs Purchased power expense $1.5 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.0) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (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 $15.1 (b) Entergy Arkansas FTRs Purchased power expense $14.5 (b) Entergy Louisiana FTRs Purchased power expense $3.3 (b) Entergy Mississippi FTRs Purchased power expense $1.6 (b) Entergy New Orleans FTRs Purchased power expense ($1.4) (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 Entergy Wholesale Commodities Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Entergy Wholesale Commodities 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 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 Entergy Wholesale Commodities 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, Entergy Wholesale Commodities Risk Control group calculates the mark-to-market for electricity swaps and options. Entergy Wholesale Commodities 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 effects are calculated for this analysis. This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of FTRs are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Entergy Wholesale Commodities Risk Control group for the unregulated business and by the System Planning and Operations Risk Control group for the Utility operating companies. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Risk Control groups report to the Vice President and Treasurer. The Accounting Policy group reports to the Chief Accounting Officer. 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 March 31, 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 $1,010 $— $— $1,010 Funds held on deposit 197 — — 197 Decommissioning trust funds (a): Equity securities 446 — — 446 Debt securities 1,060 1,189 — 2,249 Common trusts (b) 2,757 Power contracts — — 183 183 Securitization recovery trust account 52 — — 52 Escrow accounts 454 — — 454 FTRs — — 9 9 $3,219 $1,189 $192 $7,357 Liabilities: Gas hedge contracts $9 $— $— $9 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 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value (NAV) 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 NAV 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 classifie

Decommissioning Trust Funds

Decommissioning Trust Funds	3 Months Ended
	Mar. 31, 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 (NYPA currently retains the decommissioning trusts and liabilities for Indian Point 3 and FitzPatrick). The funds are invested primarily in equity securities, fixed-rate debt securities, and cash and cash equivalents. 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,203 $1,638 $1 Debt Securities 2,249 78 4 Total $5,452 $1,716 $5 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 $361 million and $342 million as of March 31, 2016 and December 31, 2015 , respectively. The amortized cost of debt securities was $2,183 million as of March 31, 2016 and $2,124 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 3.20% , an average duration of approximately 5.84 years, and an average maturity of approximately 8.91 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $38 $1 $196 $2 More than 12 months — — 73 2 Total $38 $1 $269 $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 $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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $98 $77 1 year - 5 years 855 857 5 years - 10 years 711 704 10 years - 15 years 144 124 15 years - 20 years 58 50 20 years+ 383 343 Total $2,249 $2,155 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $729 million and $493 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $10 million and $26 million , respectively, and gross losses of $3 million and $2 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $474.3 $238.5 $0.2 Debt Securities 311.2 9.5 0.8 Total $785.5 $248.0 $1.0 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 $302 million as of March 31, 2016 and $301.8 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 2.58% , an average duration of approximately 5.25 years, and an average maturity of approximately 6.16 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $7.3 $0.2 $18.1 $0.4 More than 12 months — — 11.3 0.4 Total $7.3 $0.2 $29.4 $0.8 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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $3.7 $1.8 1 year - 5 years 142.0 145.2 5 years - 10 years 138.4 138.5 10 years - 15 years 7.5 2.4 15 years - 20 years 2.1 2.0 20 years+ 17.5 14.0 Total $311.2 $303.9 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $58.6 million and $81.9 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $0.8 million and $5.1 million , respectively, and gross losses of $0.1 million and $1.3 thousand , 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $643.0 $289.3 $0.1 Debt Securities 422.2 19.0 0.8 Total $1,065.2 $308.3 $0.9 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 $407 million as of March 31, 2016 and $399.2 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 3.89% , an average duration of approximately 5.54 years, and an average maturity of approximately 10.24 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8.6 $0.1 $24.0 $0.3 More than 12 months — — 11.0 0.5 Total $8.6 $0.1 $35.0 $0.8 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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $31.9 $27.1 1 year - 5 years 114.8 124.0 5 years - 10 years 121.2 114.3 10 years - 15 years 43.6 39.3 15 years - 20 years 29.7 26.5 20 years+ 81.0 78.7 Total $422.2 $409.9 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $53.8 million and $25.6 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $0.9 million and $1.3 million , respectively, and gross losses of $0.1 million and $0.01 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $428.4 $182.7 $0.1 Debt Securities 291.4 5.5 0.4 Total $719.8 $188.2 $0.5 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 $286.9 million as of March 31, 2016 and $270.7 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 1.93% , an average duration of approximately 5.02 years, and an average maturity of approximately 6.37 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $3.9 $0.1 $45.8 $0.3 More than 12 months — — 2.4 0.1 Total $3.9 $0.1 $48.2 $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 $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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $4.6 $2.0 1 year - 5 years 180.9 181.2 5 years - 10 years 73.3 63.0 10 years - 15 years 4.5 4.4 15 years - 20 years 1.5 1.6 20 years+ 26.6 25.6 Total $291.4 $277.8 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $188.5 million and $78.4 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $1.6 million and $0.4 million , respectively, and gross losses of $0.3 million and $0.1 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 months ended March 31, 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 months ended March 31, 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 (NYPA currently retains the decommissioning trusts and liabilities for Indian Point 3 and FitzPatrick). The funds are invested primarily in equity securities, fixed-rate debt securities, and cash and cash equivalents. 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,203 $1,638 $1 Debt Securities 2,249 78 4 Total $5,452 $1,716 $5 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 $361 million and $342 million as of March 31, 2016 and December 31, 2015 , respectively. The amortized cost of debt securities was $2,183 million as of March 31, 2016 and $2,124 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 3.20% , an average duration of approximately 5.84 years, and an average maturity of approximately 8.91 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $38 $1 $196 $2 More than 12 months — — 73 2 Total $38 $1 $269 $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 $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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $98 $77 1 year - 5 years 855 857 5 years - 10 years 711 704 10 years - 15 years 144 124 15 years - 20 years 58 50 20 years+ 383 343 Total $2,249 $2,155 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $729 million and $493 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $10 million and $26 million , respectively, and gross losses of $3 million and $2 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $474.3 $238.5 $0.2 Debt Securities 311.2 9.5 0.8 Total $785.5 $248.0 $1.0 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 $302 million as of March 31, 2016 and $301.8 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 2.58% , an average duration of approximately 5.25 years, and an average maturity of approximately 6.16 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $7.3 $0.2 $18.1 $0.4 More than 12 months — — 11.3 0.4 Total $7.3 $0.2 $29.4 $0.8 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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $3.7 $1.8 1 year - 5 years 142.0 145.2 5 years - 10 years 138.4 138.5 10 years - 15 years 7.5 2.4 15 years - 20 years 2.1 2.0 20 years+ 17.5 14.0 Total $311.2 $303.9 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $58.6 million and $81.9 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $0.8 million and $5.1 million , respectively, and gross losses of $0.1 million and $1.3 thousand , 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $643.0 $289.3 $0.1 Debt Securities 422.2 19.0 0.8 Total $1,065.2 $308.3 $0.9 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 $407 million as of March 31, 2016 and $399.2 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 3.89% , an average duration of approximately 5.54 years, and an average maturity of approximately 10.24 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8.6 $0.1 $24.0 $0.3 More than 12 months — — 11.0 0.5 Total $8.6 $0.1 $35.0 $0.8 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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $31.9 $27.1 1 year - 5 years 114.8 124.0 5 years - 10 years 121.2 114.3 10 years - 15 years 43.6 39.3 15 years - 20 years 29.7 26.5 20 years+ 81.0 78.7 Total $422.2 $409.9 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $53.8 million and $25.6 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $0.9 million and $1.3 million , respectively, and gross losses of $0.1 million and $0.01 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $428.4 $182.7 $0.1 Debt Securities 291.4 5.5 0.4 Total $719.8 $188.2 $0.5 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 $286.9 million as of March 31, 2016 and $270.7 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 1.93% , an average duration of approximately 5.02 years, and an average maturity of approximately 6.37 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $3.9 $0.1 $45.8 $0.3 More than 12 months — — 2.4 0.1 Total $3.9 $0.1 $48.2 $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 $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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $4.6 $2.0 1 year - 5 years 180.9 181.2 5 years - 10 years 73.3 63.0 10 years - 15 years 4.5 4.4 15 years - 20 years 1.5 1.6 20 years+ 26.6 25.6 Total $291.4 $277.8 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $188.5 million and $78.4 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $1.6 million and $0.4 million , respectively, and gross losses of $0.3 million and $0.1 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 months ended March 31, 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 months ended March 31, 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 (NYPA currently retains the decommissioning trusts and liabilities for Indian Point 3 and FitzPatrick). The funds are invested primarily in equity securities, fixed-rate debt securities, and cash and cash equivalents. 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,203 $1,638 $1 Debt Securities 2,249 78 4 Total $5,452 $1,716 $5 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 $361 million and $342 million as of March 31, 2016 and December 31, 2015 , respectively. The amortized cost of debt securities was $2,183 million as of March 31, 2016 and $2,124 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 3.20% , an average duration of approximately 5.84 years, and an average maturity of approximately 8.91 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $38 $1 $196 $2 More than 12 months — — 73 2 Total $38 $1 $269 $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 $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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $98 $77 1 year - 5 years 855 857 5 years - 10 years 711 704 10 years - 15 years 144 124 15 years - 20 years 58 50 20 years+ 383 343 Total $2,249 $2,155 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $729 million and $493 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $10 million and $26 million , respectively, and gross losses of $3 million and $2 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $474.3 $238.5 $0.2 Debt Securities 311.2 9.5 0.8 Total $785.5 $248.0 $1.0 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 $302 million as of March 31, 2016 and $301.8 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 2.58% , an average duration of approximately 5.25 years, and an average maturity of approximately 6.16 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $7.3 $0.2 $18.1 $0.4 More than 12 months — — 11.3 0.4 Total $7.3 $0.2 $29.4 $0.8 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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $3.7 $1.8 1 year - 5 years 142.0 145.2 5 years - 10 years 138.4 138.5 10 years - 15 years 7.5 2.4 15 years - 20 years 2.1 2.0 20 years+ 17.5 14.0 Total $311.2 $303.9 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $58.6 million and $81.9 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $0.8 million and $5.1 million , respectively, and gross losses of $0.1 million and $1.3 thousand , 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $643.0 $289.3 $0.1 Debt Securities 422.2 19.0 0.8 Total $1,065.2 $308.3 $0.9 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 $407 million as of March 31, 2016 and $399.2 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 3.89% , an average duration of approximately 5.54 years, and an average maturity of approximately 10.24 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8.6 $0.1 $24.0 $0.3 More than 12 months — — 11.0 0.5 Total $8.6 $0.1 $35.0 $0.8 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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $31.9 $27.1 1 year - 5 years 114.8 124.0 5 years - 10 years 121.2 114.3 10 years - 15 years 43.6 39.3 15 years - 20 years 29.7 26.5 20 years+ 81.0 78.7 Total $422.2 $409.9 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $53.8 million and $25.6 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $0.9 million and $1.3 million , respectively, and gross losses of $0.1 million and $0.01 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $428.4 $182.7 $0.1 Debt Securities 291.4 5.5 0.4 Total $719.8 $188.2 $0.5 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 $286.9 million as of March 31, 2016 and $270.7 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 1.93% , an average duration of approximately 5.02 years, and an average maturity of approximately 6.37 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $3.9 $0.1 $45.8 $0.3 More than 12 months — — 2.4 0.1 Total $3.9 $0.1 $48.2 $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 $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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $4.6 $2.0 1 year - 5 years 180.9 181.2 5 years - 10 years 73.3 63.0 10 years - 15 years 4.5 4.4 15 years - 20 years 1.5 1.6 20 years+ 26.6 25.6 Total $291.4 $277.8 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $188.5 million and $78.4 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $1.6 million and $0.4 million , respectively, and gross losses of $0.3 million and $0.1 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 months ended March 31, 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 months ended March 31, 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 (NYPA currently retains the decommissioning trusts and liabilities for Indian Point 3 and FitzPatrick). The funds are invested primarily in equity securities, fixed-rate debt securities, and cash and cash equivalents. 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,203 $1,638 $1 Debt Securities 2,249 78 4 Total $5,452 $1,716 $5 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 $361 million and $342 million as of March 31, 2016 and December 31, 2015 , respectively. The amortized cost of debt securities was $2,183 million as of March 31, 2016 and $2,124 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 3.20% , an average duration of approximately 5.84 years, and an average maturity of approximately 8.91 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $38 $1 $196 $2 More than 12 months — — 73 2 Total $38 $1 $269 $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 $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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $98 $77 1 year - 5 years 855 857 5 years - 10 years 711 704 10 years - 15 years 144 124 15 years - 20 years 58 50 20 years+ 383 343 Total $2,249 $2,155 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $729 million and $493 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $10 million and $26 million , respectively, and gross losses of $3 million and $2 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $474.3 $238.5 $0.2 Debt Securities 311.2 9.5 0.8 Total $785.5 $248.0 $1.0 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 $302 million as of March 31, 2016 and $301.8 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 2.58% , an average duration of approximately 5.25 years, and an average maturity of approximately 6.16 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $7.3 $0.2 $18.1 $0.4 More than 12 months — — 11.3 0.4 Total $7.3 $0.2 $29.4 $0.8 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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $3.7 $1.8 1 year - 5 years 142.0 145.2 5 years - 10 years 138.4 138.5 10 years - 15 years 7.5 2.4 15 years - 20 years 2.1 2.0 20 years+ 17.5 14.0 Total $311.2 $303.9 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $58.6 million and $81.9 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $0.8 million and $5.1 million , respectively, and gross losses of $0.1 million and $1.3 thousand , 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $643.0 $289.3 $0.1 Debt Securities 422.2 19.0 0.8 Total $1,065.2 $308.3 $0.9 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 $407 million as of March 31, 2016 and $399.2 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 3.89% , an average duration of approximately 5.54 years, and an average maturity of approximately 10.24 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8.6 $0.1 $24.0 $0.3 More than 12 months — — 11.0 0.5 Total $8.6 $0.1 $35.0 $0.8 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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $31.9 $27.1 1 year - 5 years 114.8 124.0 5 years - 10 years 121.2 114.3 10 years - 15 years 43.6 39.3 15 years - 20 years 29.7 26.5 20 years+ 81.0 78.7 Total $422.2 $409.9 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $53.8 million and $25.6 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $0.9 million and $1.3 million , respectively, and gross losses of $0.1 million and $0.01 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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $428.4 $182.7 $0.1 Debt Securities 291.4 5.5 0.4 Total $719.8 $188.2 $0.5 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 $286.9 million as of March 31, 2016 and $270.7 million as of December 31, 2015 . As of March 31, 2016 , the debt securities have an average coupon rate of approximately 1.93% , an average duration of approximately 5.02 years, and an average maturity of approximately 6.37 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $3.9 $0.1 $45.8 $0.3 More than 12 months — — 2.4 0.1 Total $3.9 $0.1 $48.2 $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 $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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $4.6 $2.0 1 year - 5 years 180.9 181.2 5 years - 10 years 73.3 63.0 10 years - 15 years 4.5 4.4 15 years - 20 years 1.5 1.6 20 years+ 26.6 25.6 Total $291.4 $277.8 During the three months ended March 31, 2016 and 2015 , proceeds from the dispositions of securities amounted to $188.5 million and $78.4 million , respectively. During the three months ended March 31, 2016 and 2015 , gross gains of $1.6 million and $0.4 million , respectively, and gross losses of $0.3 million and $0.1 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 months ended March 31, 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 months ended March 31, 2016 and 2015 .

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 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 is an update to that discussion 2010-2011 IRS Audit The IRS examination of the 2010 and 2011 years has not been completed. The audit fieldwork is continuing and is expected to be completed before the end of 2016. The Revenue Agent’s Report is expected to be received shortly after the completion of field work.
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 is an update to that discussion 2010-2011 IRS Audit The IRS examination of the 2010 and 2011 years has not been completed. The audit fieldwork is continuing and is expected to be completed before the end of 2016. The Revenue Agent’s Report is expected to be received shortly after the completion of field work.
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 is an update to that discussion 2010-2011 IRS Audit The IRS examination of the 2010 and 2011 years has not been completed. The audit fieldwork is continuing and is expected to be completed before the end of 2016. The Revenue Agent’s Report is expected to be received shortly after the completion of field work.
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 is an update to that discussion 2010-2011 IRS Audit The IRS examination of the 2010 and 2011 years has not been completed. The audit fieldwork is continuing and is expected to be completed before the end of 2016. The Revenue Agent’s Report is expected to be received shortly after the completion of field work.
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 is an update to that discussion 2010-2011 IRS Audit The IRS examination of the 2010 and 2011 years has not been completed. The audit fieldwork is continuing and is expected to be completed before the end of 2016. The Revenue Agent’s Report is expected to be received shortly after the completion of field work.
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 is an update to that discussion 2010-2011 IRS Audit The IRS examination of the 2010 and 2011 years has not been completed. The audit fieldwork is continuing and is expected to be completed before the end of 2016. The Revenue Agent’s Report is expected to be received shortly after the completion of field work.
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 is an update to that discussion 2010-2011 IRS Audit The IRS examination of the 2010 and 2011 years has not been completed. The audit fieldwork is continuing and is expected to be completed before the end of 2016. The Revenue Agent’s Report is expected to be received shortly after the completion of field work.

Property, Plant, And Equipment

Property, Plant, And Equipment	3 Months Ended
	Mar. 31, 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 March 31, 2016 are $172 million for Entergy, $29.3 million for Entergy Arkansas, $40.5 million for Entergy Louisiana, $2.5 million for Entergy Mississippi, $0.4 million for Entergy New Orleans, $17.3 million for Entergy Texas, and $24.7 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 March 31, 2016 are $172 million for Entergy, $29.3 million for Entergy Arkansas, $40.5 million for Entergy Louisiana, $2.5 million for Entergy Mississippi, $0.4 million for Entergy New Orleans, $17.3 million for Entergy Texas, and $24.7 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 March 31, 2016 are $172 million for Entergy, $29.3 million for Entergy Arkansas, $40.5 million for Entergy Louisiana, $2.5 million for Entergy Mississippi, $0.4 million for Entergy New Orleans, $17.3 million for Entergy Texas, and $24.7 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 March 31, 2016 are $172 million for Entergy, $29.3 million for Entergy Arkansas, $40.5 million for Entergy Louisiana, $2.5 million for Entergy Mississippi, $0.4 million for Entergy New Orleans, $17.3 million for Entergy Texas, and $24.7 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 March 31, 2016 are $172 million for Entergy, $29.3 million for Entergy Arkansas, $40.5 million for Entergy Louisiana, $2.5 million for Entergy Mississippi, $0.4 million for Entergy New Orleans, $17.3 million for Entergy Texas, and $24.7 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 March 31, 2016 are $172 million for Entergy, $29.3 million for Entergy Arkansas, $40.5 million for Entergy Louisiana, $2.5 million for Entergy Mississippi, $0.4 million for Entergy New Orleans, $17.3 million for Entergy Texas, and $24.7 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 March 31, 2016 are $172 million for Entergy, $29.3 million for Entergy Arkansas, $40.5 million for Entergy Louisiana, $2.5 million for Entergy Mississippi, $0.4 million for Entergy New Orleans, $17.3 million for Entergy Texas, and $24.7 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	3 Months Ended
	Mar. 31, 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 $9.2 million and $21 million in the three months ended March 31, 2016 and 2015 , respectively. 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 and $37.6 million in the three months ended March 31, 2016 and 2015 , respectively.
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 $9.2 million and $21 million in the three months ended March 31, 2016 and 2015 , respectively. 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 and $37.6 million in the three months ended March 31, 2016 and 2015 , respectively.
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 $9.2 million and $21 million in the three months ended March 31, 2016 and 2015 , respectively. 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 and $37.6 million in the three months ended March 31, 2016 and 2015 , respectively.
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 $9.2 million and $21 million in the three months ended March 31, 2016 and 2015 , respectively. 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 and $37.6 million in the three months ended March 31, 2016 and 2015 , respectively.
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 $9.2 million and $21 million in the three months ended March 31, 2016 and 2015 , respectively. 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 and $37.6 million in the three months ended March 31, 2016 and 2015 , respectively.
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 $9.2 million and $21 million in the three months ended March 31, 2016 and 2015 , respectively. 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 and $37.6 million in the three months ended March 31, 2016 and 2015 , respectively.
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 $9.2 million and $21 million in the three months ended March 31, 2016 and 2015 , respectively. 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 and $37.6 million in the three months ended March 31, 2016 and 2015 , respectively.

Acquisitions Acquisitions

Acquisitions Acquisitions	3 Months Ended
	Mar. 31, 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 $948 million (approximately $237 million for each power block and associated assets), subject to further adjustment.
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 $948 million (approximately $237 million for each power block and associated assets), subject to further adjustment.
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 $948 million (approximately $237 million for each power block and associated assets), subject to further adjustment.
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 $948 million (approximately $237 million for each power block and associated assets), subject to further adjustment.

Equity (Tables)

Equity (Tables)	3 Months Ended
	Mar. 31, 2016
Schedule Of Earnings Per Share Basic And Diluted	The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Three Months Ended March 31, 2016 2015 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $230.0 178.6 $1.29 $298.1 179.7 $1.66 Average dilutive effect of: Stock options 0.1 — 0.5 (0.01 ) Other equity plans 0.3 (0.01 ) 0.3 — Diluted earnings per share $230.0 179.0 $1.28 $298.1 180.5 $1.65
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 March 31, 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 90,307 — 25,032 (284 ) 115,055 Amounts reclassified from accumulated other comprehensive income (loss) (99,813 ) 7,562 (1,963 ) — (94,214 ) Net other comprehensive income (loss) for the period (9,506 ) 7,562 23,069 (284 ) 20,841 Ending balance, March 31, 2016 $96,464 ($459,042 ) $390,626 $1,744 $29,792 The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 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 (20,896 ) 13 12,658 (551 ) (8,776 ) Amounts reclassified from accumulated other comprehensive income (loss) (8,434 ) 8,435 (8,655 ) — (8,654 ) Net other comprehensive income (loss) for the period (29,330 ) 8,448 4,003 (551 ) (17,430 ) Ending balance, March 31, 2015 $68,788 ($561,341 ) $430,698 $2,118 ($59,737 )
Reclassification out of Accumulated Other Comprehensive Income	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended March 31, 2016 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $153,958 Competitive business operating revenues Interest rate swaps (400 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 153,558 (53,745 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $99,813 Pension and other postretirement liabilities Amortization of prior-service credit $7,355 (a) Amortization of loss (15,175 ) (a) Total amortization (7,820 ) 258 Income taxes Total amortization (net of tax) ($7,562 ) Net unrealized investment gain (loss) Realized gain (loss) $3,850 Interest and investment income (1,887 ) Income taxes Total realized investment gain (loss) (net of tax) $1,963 Total reclassifications for the period (net of tax) $94,214 (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 March 31, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $13,522 Competitive business operating revenues Interest rate swaps (546 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 12,976 (4,542 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $8,434 Pension and other postretirement liabilities Amortization of prior-service credit $5,986 (a) Amortization of loss (17,588 ) (a) Total amortization (11,602 ) 3,167 Income taxes Total amortization (net of tax) ($8,435 ) Net unrealized investment gain (loss) Realized gain (loss) $16,970 Interest and investment income (8,315 ) Income taxes Total realized investment gain (loss) (net of tax) $8,655 Total reclassifications for the period (net of tax) $8,654 (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 March 31, 2016: Pension and Other (In Thousands) Beginning balance, January 1, 2016 ($56,412 ) Amounts reclassified from accumulated other (263 ) Net other comprehensive income (loss) for the period (263 ) Ending balance, March 31, 2016 ($56,675 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended March 31, 2015: Pension and Other (In Thousands) Beginning balance, January 1, 2015 ($79,223 ) Amounts reclassified from accumulated other 380 Net other comprehensive income (loss) for the period 380 Ending balance, March 31, 2015 ($78,843 )
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 March 31, 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 (1,569 ) (a) Total amortization 378 (115 ) Income taxes Total amortization (net of tax) 263 Total reclassifications for the period (net of tax) $263 (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 March 31, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,867 (a) Amortization of loss (2,535 ) (a) Total amortization (668 ) 288 Income taxes Total amortization (net of tax) (380 ) Total reclassifications for the period (net of tax) ($380 ) (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, 24

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Tables)	3 Months Ended
	Mar. 31, 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 March 31, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $616 $7 $2,877
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2016 Letters of Credit Outstanding as of March 31, 2016 Entergy Arkansas April 2016 $20 million (b) 1.93% $— $— Entergy Arkansas August 2020 $150 million (c) 1.68% $— $— Entergy Louisiana August 2020 $350 million (d) 1.68% $— $3.1 million Entergy Mississippi May 2016 $37.5 million (e) 1.93% $— $— Entergy Mississippi May 2016 $35 million (e) 1.93% $— $— Entergy Mississippi May 2016 $20 million (e) 1.93% $— $— Entergy Mississippi May 2016 $10 million (e) 1.93% $— $— Entergy New Orleans November 2018 $25 million 2.18% $— $— Entergy Texas August 2020 $150 million (f) 1.93% $— $1.3 million (a) The interest rate is the rate as of March 31, 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. The credit facility expired in April 2016. Entergy Arkansas plans to renew the credit facility. (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. Entergy Mississippi expects to renew its credit facilities prior to expiration. (f) 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 March 31, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $7.0 million Entergy Mississippi $40 million 0.70% $4.4 million Entergy New Orleans $15 million 0.75% $6.2 million Entergy Texas $50 million 0.70% $5.6 million (a) The amount for Entergy Mississippi includes $0.4 million related to FTR exposure. See Note 8 to the financial statements herein for discussion of FTRs.
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 March 31, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $— System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	he nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2016 : Company Expiration Date (a) Amount of Facility Weighted Average Interest Rate on Borrowings (b) Amount Outstanding as of March 31, 2016 (Dollars in Millions) Entergy Arkansas VIE June 2016 $85 n/a $— Entergy Louisiana River Bend VIE June 2016 $100 n/a $— Entergy Louisiana Waterford VIE June 2016 $90 1.86% $77.5 (c) System Energy VIE June 2016 $125 2.01% $111 (c) (a) Prior to expiration, the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy each plan to renew its credit facility. (b) 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. (c) 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 March 31, 2016 as follows: Company Description Amount Entergy Arkansas VIE 3.23% Series J due July 2016 $55 million 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 March 31, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,296,872 $14,811,845 Entergy Arkansas $2,777,649 $2,726,079 Entergy Louisiana $5,620,234 $5,967,996 Entergy Mississippi $1,045,430 $1,100,469 Entergy New Orleans $449,892 $443,145 Entergy Texas $1,552,741 $1,702,601 System Energy $572,742 $550,080 (a) The values exclude lease obligations of $56 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. 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 March 31, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2016 Letters of Credit Outstanding as of March 31, 2016 Entergy Arkansas April 2016 $20 million (b) 1.93% $— $— Entergy Arkansas August 2020 $150 million (c) 1.68% $— $— Entergy Louisiana August 2020 $350 million (d) 1.68% $— $3.1 million Entergy Mississippi May 2016 $37.5 million (e) 1.93% $— $— Entergy Mississippi May 2016 $35 million (e) 1.93% $— $— Entergy Mississippi May 2016 $20 million (e) 1.93% $— $— Entergy Mississippi May 2016 $10 million (e) 1.93% $— $— Entergy New Orleans November 2018 $25 million 2.18% $— $— Entergy Texas August 2020 $150 million (f) 1.93% $— $1.3 million (a) The interest rate is the rate as of March 31, 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. The credit facility expired in April 2016. Entergy Arkansas plans to renew the credit facility. (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. Entergy Mississippi expects to renew its credit facilities prior to expiration. (f) 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 March 31, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $7.0 million Entergy Mississippi $40 million 0.70% $4.4 million Entergy New Orleans $15 million 0.75% $6.2 million Entergy Texas $50 million 0.70% $5.6 million (a) The amount for Entergy Mississippi includes $0.4 million related to FTR exposure. See Note 8 to the financial statements herein for discussion of FTRs.
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 March 31, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $— System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	he nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2016 : Company Expiration Date (a) Amount of Facility Weighted Average Interest Rate on Borrowings (b) Amount Outstanding as of March 31, 2016 (Dollars in Millions) Entergy Arkansas VIE June 2016 $85 n/a $— Entergy Louisiana River Bend VIE June 2016 $100 n/a $— Entergy Louisiana Waterford VIE June 2016 $90 1.86% $77.5 (c) System Energy VIE June 2016 $125 2.01% $111 (c) (a) Prior to expiration, the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy each plan to renew its credit facility. (b) 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. (c) 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 March 31, 2016 as follows: Company Description Amount Entergy Arkansas VIE 3.23% Series J due July 2016 $55 million 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 March 31, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,296,872 $14,811,845 Entergy Arkansas $2,777,649 $2,726,079 Entergy Louisiana $5,620,234 $5,967,996 Entergy Mississippi $1,045,430 $1,100,469 Entergy New Orleans $449,892 $443,145 Entergy Texas $1,552,741 $1,702,601 System Energy $572,742 $550,080 (a) The values exclude lease obligations of $56 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. 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 March 31, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2016 Letters of Credit Outstanding as of March 31, 2016 Entergy Arkansas April 2016 $20 million (b) 1.93% $— $— Entergy Arkansas August 2020 $150 million (c) 1.68% $— $— Entergy Louisiana August 2020 $350 million (d) 1.68% $— $3.1 million Entergy Mississippi May 2016 $37.5 million (e) 1.93% $— $— Entergy Mississippi May 2016 $35 million (e) 1.93% $— $— Entergy Mississippi May 2016 $20 million (e) 1.93% $— $— Entergy Mississippi May 2016 $10 million (e) 1.93% $— $— Entergy New Orleans November 2018 $25 million 2.18% $— $— Entergy Texas August 2020 $150 million (f) 1.93% $— $1.3 million (a) The interest rate is the rate as of March 31, 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. The credit facility expired in April 2016. Entergy Arkansas plans to renew the credit facility. (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. Entergy Mississippi expects to renew its credit facilities prior to expiration. (f) 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 March 31, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $7.0 million Entergy Mississippi $40 million 0.70% $4.4 million Entergy New Orleans $15 million 0.75% $6.2 million Entergy Texas $50 million 0.70% $5.6 million (a) The amount for Entergy Mississippi includes $0.4 million related to FTR exposure. See Note 8 to the financial statements herein for discussion of FTRs.
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 March 31, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $— System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	he nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2016 : Company Expiration Date (a) Amount of Facility Weighted Average Interest Rate on Borrowings (b) Amount Outstanding as of March 31, 2016 (Dollars in Millions) Entergy Arkansas VIE June 2016 $85 n/a $— Entergy Louisiana River Bend VIE June 2016 $100 n/a $— Entergy Louisiana Waterford VIE June 2016 $90 1.86% $77.5 (c) System Energy VIE June 2016 $125 2.01% $111 (c) (a) Prior to expiration, the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy each plan to renew its credit facility. (b) 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. (c) 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 March 31, 2016 as follows: Company Description Amount Entergy Arkansas VIE 3.23% Series J due July 2016 $55 million 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 March 31, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,296,872 $14,811,845 Entergy Arkansas $2,777,649 $2,726,079 Entergy Louisiana $5,620,234 $5,967,996 Entergy Mississippi $1,045,430 $1,100,469 Entergy New Orleans $449,892 $443,145 Entergy Texas $1,552,741 $1,702,601 System Energy $572,742 $550,080 (a) The values exclude lease obligations of $56 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. 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 March 31, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2016 Letters of Credit Outstanding as of March 31, 2016 Entergy Arkansas April 2016 $20 million (b) 1.93% $— $— Entergy Arkansas August 2020 $150 million (c) 1.68% $— $— Entergy Louisiana August 2020 $350 million (d) 1.68% $— $3.1 million Entergy Mississippi May 2016 $37.5 million (e) 1.93% $— $— Entergy Mississippi May 2016 $35 million (e) 1.93% $— $— Entergy Mississippi May 2016 $20 million (e) 1.93% $— $— Entergy Mississippi May 2016 $10 million (e) 1.93% $— $— Entergy New Orleans November 2018 $25 million 2.18% $— $— Entergy Texas August 2020 $150 million (f) 1.93% $— $1.3 million (a) The interest rate is the rate as of March 31, 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. The credit facility expired in April 2016. Entergy Arkansas plans to renew the credit facility. (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. Entergy Mississippi expects to renew its credit facilities prior to expiration. (f) 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 March 31, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $7.0 million Entergy Mississippi $40 million 0.70% $4.4 million Entergy New Orleans $15 million 0.75% $6.2 million Entergy Texas $50 million 0.70% $5.6 million (a) The amount for Entergy Mississippi includes $0.4 million related to FTR exposure. See Note 8 to the financial statements herein for discussion of FTRs.
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 March 31, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $— System Energy $200 $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,296,872 $14,811,845 Entergy Arkansas $2,777,649 $2,726,079 Entergy Louisiana $5,620,234 $5,967,996 Entergy Mississippi $1,045,430 $1,100,469 Entergy New Orleans $449,892 $443,145 Entergy Texas $1,552,741 $1,702,601 System Energy $572,742 $550,080 (a) The values exclude lease obligations of $56 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. 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 March 31, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2016 Letters of Credit Outstanding as of March 31, 2016 Entergy Arkansas April 2016 $20 million (b) 1.93% $— $— Entergy Arkansas August 2020 $150 million (c) 1.68% $— $— Entergy Louisiana August 2020 $350 million (d) 1.68% $— $3.1 million Entergy Mississippi May 2016 $37.5 million (e) 1.93% $— $— Entergy Mississippi May 2016 $35 million (e) 1.93% $— $— Entergy Mississippi May 2016 $20 million (e) 1.93% $— $— Entergy Mississippi May 2016 $10 million (e) 1.93% $— $— Entergy New Orleans November 2018 $25 million 2.18% $— $— Entergy Texas August 2020 $150 million (f) 1.93% $— $1.3 million (a) The interest rate is the rate as of March 31, 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. The credit facility expired in April 2016. Entergy Arkansas plans to renew the credit facility. (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. Entergy Mississippi expects to renew its credit facilities prior to expiration. (f) 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 March 31, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $7.0 million Entergy Mississippi $40 million 0.70% $4.4 million Entergy New Orleans $15 million 0.75% $6.2 million Entergy Texas $50 million 0.70% $5.6 million (a) The amount for Entergy Mississippi includes $0.4 million related to FTR exposure. See Note 8 to the financial statements herein for discussion of FTRs.
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 March 31, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $— System Energy $200 $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,296,872 $14,811,845 Entergy Arkansas $2,777,649 $2,726,079 Entergy Louisiana $5,620,234 $5,967,996 Entergy Mississippi $1,045,430 $1,100,469 Entergy New Orleans $449,892 $443,145 Entergy Texas $1,552,741 $1,702,601 System Energy $572,742 $550,080 (a) The values exclude lease obligations of $56 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. 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 March 31, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2016 Letters of Credit Outstanding as of March 31, 2016 Entergy Arkansas April 2016 $20 million (b) 1.93% $— $— Entergy Arkansas August 2020 $150 million (c) 1.68% $— $— Entergy Louisiana August 2020 $350 million (d) 1.68% $— $3.1 million Entergy Mississippi May 2016 $37.5 million (e) 1.93% $— $— Entergy Mississippi May 2016 $35 million (e) 1.93% $— $— Entergy Mississippi May 2016 $20 million (e) 1.93% $— $— Entergy Mississippi May 2016 $10 million (e) 1.93% $— $— Entergy New Orleans November 2018 $25 million 2.18% $— $— Entergy Texas August 2020 $150 million (f) 1.93% $— $1.3 million (a) The interest rate is the rate as of March 31, 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. The credit facility expired in April 2016. Entergy Arkansas plans to renew the credit facility. (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. Entergy Mississippi expects to renew its credit facilities prior to expiration. (f) 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 March 31, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $7.0 million Entergy Mississippi $40 million 0.70% $4.4 million Entergy New Orleans $15 million 0.75% $6.2 million Entergy Texas $50 million 0.70% $5.6 million (a) The amount for Entergy Mississippi includes $0.4 million related to FTR exposure. See Note 8 to the financial statements herein for discussion of FTRs.
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 March 31, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $— System Energy $200 $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,296,872 $14,811,845 Entergy Arkansas $2,777,649 $2,726,079 Entergy Louisiana $5,620,234 $5,967,996 Entergy Mississippi $1,045,430 $1,100,469 Entergy New Orleans $449,892 $443,145 Entergy Texas $1,552,741 $1,702,601 System Energy $572,742 $550,080 (a) The values exclude lease obligations of $56 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. 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 March 31, 2016 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $100 $— Entergy Texas $200 $— System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	he nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of March 31, 2016 : Company Expiration Date (a) Amount of Facility Weighted Average Interest Rate on Borrowings (b) Amount Outstanding as of March 31, 2016 (Dollars in Millions) Entergy Arkansas VIE June 2016 $85 n/a $— Entergy Louisiana River Bend VIE June 2016 $100 n/a $— Entergy Louisiana Waterford VIE June 2016 $90 1.86% $77.5 (c) System Energy VIE June 2016 $125 2.01% $111 (c) (a) Prior to expiration, the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy each plan to renew its credit facility. (b) 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. (c) 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 March 31, 2016 as follows: Company Description Amount Entergy Arkansas VIE 3.23% Series J due July 2016 $55 million 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 March 31, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,296,872 $14,811,845 Entergy Arkansas $2,777,649 $2,726,079 Entergy Louisiana $5,620,234 $5,967,996 Entergy Mississippi $1,045,430 $1,100,469 Entergy New Orleans $449,892 $443,145 Entergy Texas $1,552,741 $1,702,601 System Energy $572,742 $550,080 (a) The values exclude lease obligations of $56 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. 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) - Parent Company [Member]	3 Months Ended
	Mar. 31, 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 March 31, 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 $0.4 $0.4 Compensation cost capitalized as part of fixed assets and inventory $0.2 $0.2
Financial Information For Restricted Stock	The following table includes financial information for other outstanding equity awards for the three months ended March 31, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $8.4 $8.1 Tax benefit recognized in Entergy’s net income $3.2 $3.1 Compensation cost capitalized as part of fixed assets and inventory $1.8 $1.5

Retirement And Other Postreti26

Retirement And Other Postretirement Benefits (Tables)	3 Months Ended
	Mar. 31, 2016
Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Reclassification out of Accumulated Other Comprehensive Income, amortization	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 first quarters of 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($113 ) $7,355 Amortization of loss (12,482 ) (2,063 ) (630 ) (15,175 ) ($12,752 ) $5,675 ($743 ) ($7,820 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (731 ) (2 ) (1,569 ) ($836 ) $1,216 ($2 ) $378 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($107 ) $5,986 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($659 ) ($11,602 ) Entergy Louisiana Amortization of prior service credit $— $1,867 $— $1,867 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($5 ) ($668 )
Parent Company [Member] | 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 first 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 Special termination benefit — 76 Net pension costs $52,942 $80,248
Parent Company [Member] | 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 first 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 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 first quarters of 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 $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
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of March 31, 2016 , Entergy had contributed $88.2 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 $82,831 $83,909 $19,913 $10,694 $15,770 $20,206 Pension contributions made through March 2016 $19,494 $20,195 $4,946 $2,434 $3,798 $4,613 Remaining estimated pension contributions to be made in 2016 $63,337 $63,714 $14,967 $8,260 $11,972 $15,593
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 first quarters of 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 $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 1,064 731 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,913 ($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
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 first quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost first quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost first quarter 2015 $113 $68 $59 $16 $149
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Reclassification out of Accumulated Other Comprehensive Income, amortization	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 first quarters of 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($270 ) $7,738 ($113 ) $7,355 Amortization of loss (12,482 ) (2,063 ) (630 ) (15,175 ) ($12,752 ) $5,675 ($743 ) ($7,820 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (731 ) (2 ) (1,569 ) ($836 ) $1,216 ($2 ) $378 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($107 ) $5,986 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($659 ) ($11,602 ) Entergy Louisiana Amortization of prior service credit $— $1,867 $— $1,867 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($5 ) ($668 )
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 first quarters of 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 $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
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of March 31, 2016 , Entergy had contributed $88.2 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 $82,831 $83,909 $19,913 $10,694 $15,770 $20,206 Pension contributions made through March 2016 $19,494 $20,195 $4,946 $2,434 $3,798 $4,613 Remaining estimated pension contributions to be made in 2016 $63,337 $63,714 $14,967 $8,260 $11,972 $15,593
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 first quarters of 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 $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 1,064 731 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,913 ($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
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 first quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost first quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost first quarter 2015 $113 $68 $59 $16 $149
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 first quarters of 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 $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
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of March 31, 2016 , Entergy had contributed $88.2 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 $82,831 $83,909 $19,913 $10,694 $15,770 $20,206 Pension contributions made through March 2016 $19,494 $20,195 $4,946 $2,434 $3,798 $4,613 Remaining estimated pension contributions to be made in 2016 $63,337 $63,714 $14,967 $8,260 $11,972 $15,593
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 first quarters of 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 $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 1,064 731 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,913 ($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
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 first quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost first quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost first quarter 2015 $113 $68 $59 $16 $149
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 first quarters of 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 $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
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of March 31, 2016 , Entergy had contributed $88.2 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 $82,831 $83,909 $19,913 $10,694 $15,770 $20,206 Pension contributions made through March 2016 $19,494 $20,195 $4,946 $2,434 $3,798 $4,613 Remaining estimated pension contributions to be made in 2016 $63,337 $63,714 $14,967 $8,260 $11,972 $15,593
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 first quarters of 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 $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 1,064 731 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,913 ($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
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 first quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost first quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost first quarter 2015 $113 $68 $59 $16 $149
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 first quarters of 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 $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
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of March 31, 2016 , Entergy had contributed $88.2 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 $82,831 $83,909 $19,913 $10,694 $15,770 $20,206 Pension contributions made through March 2016 $19,494 $20,195 $4,946 $2,434 $3,798 $4,613 Remaining estimated pension contributions to be made in 2016 $63,337 $63,714 $14,967 $8,260 $11,972 $15,593
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 first quarters of 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 $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 1,064 731 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,913 ($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
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 first quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost first quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost first quarter 2015 $113 $68 $59 $16 $149
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 first quarters of 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 $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
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of March 31, 2016 , Entergy had contributed $88.2 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 $82,831 $83,909 $19,913 $10,694 $15,770 $20,206 Pension contributions made through March 2016 $19,494 $20,195 $4,946 $2,434 $3,798 $4,613 Remaining estimated pension contributions to be made in 2016 $63,337 $63,714 $14,967 $8,260 $11,972 $15,593
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 first quarters of 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 $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 1,064 731 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,913 ($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

Business Segment Information (T

Business Segment Information (Tables)	3 Months Ended
	Mar. 31, 2016
Parent Company [Member]
Segment Financial Information	Entergy’s segment financial information for the first quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,087,793 $522,079 $— ($20 ) $2,609,852 Income taxes $107,836 $52,314 ($20,205 ) $— $139,945 Consolidated net income (loss) $199,651 $79,557 ($12,067 ) ($31,899 ) $235,242 2015 Operating revenues $2,277,510 $642,590 $— ($10 ) $2,920,090 Income taxes $91,251 $70,190 ($10,970 ) $— $150,471 Consolidated net income (loss) $227,750 $123,432 ($16,354 ) ($31,899 ) $302,929 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 Valu28

Risk Management And Fair Values (Tables)	3 Months Ended
	Mar. 31, 2016
Fair Values Of Derivative Instruments	The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 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) $120 ($26) $94 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $20 ($1) $19 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) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $94 ($24) $70 Entergy Wholesale Commodities FTRs Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $49 ($49) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $9 $— $9 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 March 31, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $139 Competitive businesses operating revenues $154 2015 Electricity swaps and options ($32) Competitive businesses operating revenues $14 (a) Before taxes of $54 million and $5 million for the three months ended March 31, 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 March 31, 2016 and 2015 are as follows: Instrument Amount of gain (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) ($24) FTRs $— Purchased power expense (b) $21 Electricity swaps and options de-designated as hedged items $25 Competitive business operating revenues $— 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($19) FTRs $— Purchased power expense (b) $33 Electricity swaps and options de-designated as hedged items $4 Competitive business operating revenues ($34) (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	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 March 31, 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 $1,010 $— $— $1,010 Funds held on deposit 197 — — 197 Decommissioning trust funds (a): Equity securities 446 — — 446 Debt securities 1,060 1,189 — 2,249 Common trusts (b) 2,757 Power contracts — — 183 183 Securitization recovery trust account 52 — — 52 Escrow accounts 454 — — 454 FTRs — — 9 9 $3,219 $1,189 $192 $7,357 Liabilities: Gas hedge contracts $9 $— $— $9 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 March 31, 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 — — (35 ) — Included in OCI 139 — (26 ) — Included as a regulatory liability/asset — 7 — 1 Purchases — — 10 — Settlements (145 ) (21 ) (19 ) (33 ) Balance as of March 31, $183 $9 $145 $15 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is $6 million for the three months ended March 31, 2016 and ($87) million for the three months ended March 31, 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 March 31, 2016 : Transaction Type Fair Value as of March 31, 2016 Significant Unobservable Inputs Range from Average % Effect on Fair Value (In Millions) (In Millions) Power contracts - electricity swaps $149 Unit contingent discount +/- 3% $7 Power contracts - electricity options $34 Implied volatility +/- 30% $10
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 March 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $3.7 Entergy Arkansas FTRs Prepayments and other $3.3 Entergy Louisiana FTRs Prepayments and other $0.9 Entergy Mississippi FTRs Prepayments and other $0.6 Entergy New Orleans FTRs Prepayments and other $0.9 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.6 Entergy Louisiana Natural gas swaps Other current liabilities $1.8 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) Excludes letters of credit in the amount of $0.4 million posted by Entergy Mississippi as of March 31, 2016. No cash collateral was required to be posted as of March 31, 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 March 31, 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 ($19.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.1) (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 $7.8 (b) Entergy Arkansas FTRs Purchased power expense $10.5 (b) Entergy Louisiana FTRs Purchased power expense $0.8 (b) Entergy Mississippi FTRs Purchased power expense $0.5 (b) Entergy New Orleans FTRs Purchased power expense $1.5 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.0) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (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 $15.1 (b) Entergy Arkansas FTRs Purchased power expense $14.5 (b) Entergy Louisiana FTRs Purchased power expense $3.3 (b) Entergy Mississippi FTRs Purchased power expense $1.6 (b) Entergy New Orleans FTRs Purchased power expense ($1.4) (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: Temporary cash investments $13.4 $— $— $13.4 Decommissioning trust funds (a): Equity securities 5.2 — — 5.2 Debt securities 102.3 208.9 — 311.2 Common trusts (b) 469.1 Securitization recovery trust account 7.6 — — 7.6 Escrow accounts 19.3 — — 19.3 FTRs — — 3.7 3.7 $147.8 $208.9 $3.7 $829.5 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 March 31, 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 Gains (losses) included as a regulatory liability/asset 3.6 5.3 (0.7 ) (0.4 ) 0.2 Settlements (7.8 ) (10.5 ) (0.8 ) (0.5 ) (1.5 ) Balance as of March 31, $3.7 $3.3 $0.9 $0.6 $0.9 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 March 31, 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 Gains (losses) included as a regulatory liability/asset 15.0 (2.2 ) 0.8 (1.1 ) (10.3 ) Settlements (15.1 ) (14.5 ) (3.3 ) (1.6 ) 1.4 Balance as of March 31, $0.6 $8.8 $0.9 $1.4 $3.4
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 March 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $3.7 Entergy Arkansas FTRs Prepayments and other $3.3 Entergy Louisiana FTRs Prepayments and other $0.9 Entergy Mississippi FTRs Prepayments and other $0.6 Entergy New Orleans FTRs Prepayments and other $0.9 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.6 Entergy Louisiana Natural gas swaps Other current liabilities $1.8 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) Excludes letters of credit in the amount of $0.4 million posted by Entergy Mississippi as of March 31, 2016. No cash collateral was required to be posted as of March 31, 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 March 31, 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 ($19.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.1) (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 $7.8 (b) Entergy Arkansas FTRs Purchased power expense $10.5 (b) Entergy Louisiana FTRs Purchased power expense $0.8 (b) Entergy Mississippi FTRs Purchased power expense $0.5 (b) Entergy New Orleans FTRs Purchased power expense $1.5 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.0) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (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 $15.1 (b) Entergy Arkansas FTRs Purchased power expense $14.5 (b) Entergy Louisiana FTRs Purchased power expense $3.3 (b) Entergy Mississippi FTRs Purchased power expense $1.6 (b) Entergy New Orleans FTRs Purchased power expense ($1.4) (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 $100.0 $— $— $100.0 Funds held on deposit 196.6 — — 196.6 Decommissioning trust funds (a): Equity securities 8.5 — — 8.5 Debt securities 154.5 267.7 — 422.2 Common trusts (b) 634.5 Escrow accounts 304.9 — — 304.9 Securitization recovery trust account 8.7 — — 8.7 FTRs — — 3.3 3.3 $773.2 $267.7 $3.3 $1,678.7 Liabilities: Gas hedge contracts $7.6 $— $— $7.6 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 March 31, 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 Gains (losses) included as a regulatory liability/asset 3.6 5.3 (0.7 ) (0.4 ) 0.2 Settlements (7.8 ) (10.5 ) (0.8 ) (0.5 ) (1.5 ) Balance as of March 31, $3.7 $3.3 $0.9 $0.6 $0.9 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 March 31, 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 Gains (losses) included as a regulatory liability/asset 15.0 (2.2 ) 0.8 (1.1 ) (10.3 ) Settlements (15.1 ) (14.5 ) (3.3 ) (1.6 ) 1.4 Balance as of March 31, $0.6 $8.8 $0.9 $1.4 $3.4
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 March 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $3.7 Entergy Arkansas FTRs Prepayments and other $3.3 Entergy Louisiana FTRs Prepayments and other $0.9 Entergy Mississippi FTRs Prepayments and other $0.6 Entergy New Orleans FTRs Prepayments and other $0.9 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.6 Entergy Louisiana Natural gas swaps Other current liabilities $1.8 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) Excludes letters of credit in the amount of $0.4 million posted by Entergy Mississippi as of March 31, 2016. No cash collateral was required to be posted as of March 31, 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 March 31, 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 ($19.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.1) (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 $7.8 (b) Entergy Arkansas FTRs Purchased power expense $10.5 (b) Entergy Louisiana FTRs Purchased power expense $0.8 (b) Entergy Mississippi FTRs Purchased power expense $0.5 (b) Entergy New Orleans FTRs Purchased power expense $1.5 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.0) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (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 $15.1 (b) Entergy Arkansas FTRs Purchased power expense $14.5 (b) Entergy Louisiana FTRs Purchased power expense $3.3 (b) Entergy Mississippi FTRs Purchased power expense $1.6 (b) Entergy New Orleans FTRs Purchased power expense ($1.4) (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 $112.7 $— $— $112.7 Escrow accounts 41.8 — — 41.8 FTRs — — 0.9 0.9 $154.5 $— $0.9 $155.4 Liabilities: Gas hedge contracts $1.8 $— $— $1.8 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 March 31, 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 Gains (losses) included as a regulatory liability/asset 3.6 5.3 (0.7 ) (0.4 ) 0.2 Settlements (7.8 ) (10.5 ) (0.8 ) (0.5 ) (1.5 ) Balance as of March 31, $3.7 $3.3 $0.9 $0.6 $0.9 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 March 31, 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 Gains (losses) included as a regulatory liability/asset 15.0 (2.2 ) 0.8 (1.1 ) (10.3 ) Settlements (15.1 ) (14.5 ) (3.3 ) (1.6 ) 1.4 Balance as of March 31, $0.6 $8.8 $0.9 $1.4 $3.4
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 March 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $3.7 Entergy Arkansas FTRs Prepayments and other $3.3 Entergy Louisiana FTRs Prepayments and other $0.9 Entergy Mississippi FTRs Prepayments and other $0.6 Entergy New Orleans FTRs Prepayments and other $0.9 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.6 Entergy Louisiana Natural gas swaps Other current liabilities $1.8 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) Excludes letters of credit in the amount of $0.4 million posted by Entergy Mississippi as of March 31, 2016. No cash collateral was required to be posted as of March 31, 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 March 31, 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 ($19.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.1) (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 $7.8 (b) Entergy Arkansas FTRs Purchased power expense $10.5 (b) Entergy Louisiana FTRs Purchased power expense $0.8 (b) Entergy Mississippi FTRs Purchased power expense $0.5 (b) Entergy New Orleans FTRs Purchased power expense $1.5 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.0) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (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 $15.1 (b) Entergy Arkansas FTRs Purchased power expense $14.5 (b) Entergy Louisiana FTRs Purchased power expense $3.3 (b) Entergy Mississippi FTRs Purchased power expense $1.6 (b) Entergy New Orleans FTRs Purchased power expense ($1.4) (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 $5.3 $— $— $5.3 Securitization recovery trust account 7.4 — — 7.4 Escrow accounts 88.2 — — 88.2 FTRs — — 0.6 0.6 $100.9 $— $0.6 $101.5 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 March 31, 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 Gains (losses) included as a regulatory liability/asset 3.6 5.3 (0.7 ) (0.4 ) 0.2 Settlements (7.8 ) (10.5 ) (0.8 ) (0.5 ) (1.5 ) Balance as of March 31, $3.7 $3.3 $0.9 $0.6 $0.9 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 March 31, 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 Gains (losses) included as a regulatory liability/asset 15.0 (2.2 ) 0.8 (1.1 ) (10.3 ) Settlements (15.1 ) (14.5 ) (3.3 ) (1.6 ) 1.4 Balance as of March 31, $0.6 $8.8 $0.9 $1.4 $3.4
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 March 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: FTRs Prepayments and other $3.7 Entergy Arkansas FTRs Prepayments and other $3.3 Entergy Louisiana FTRs Prepayments and other $0.9 Entergy Mississippi FTRs Prepayments and other $0.6 Entergy New Orleans FTRs Prepayments and other $0.9 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $7.6 Entergy Louisiana Natural gas swaps Other current liabilities $1.8 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) Excludes letters of credit in the amount of $0.4 million posted by Entergy Mississippi as of March 31, 2016. No cash collateral was required to be posted as of March 31, 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 March 31, 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 ($19.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.1) (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 $7.8 (b) Entergy Arkansas FTRs Purchased power expense $10.5 (b) Entergy Louisiana FTRs Purchased power expense $0.8 (b) Entergy Mississippi FTRs Purchased power expense $0.5 (b) Entergy New Orleans FTRs Purchased power expense $1.5 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($16.0) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (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 $15.1 (b) Entergy Arkansas FTRs Purchased power expense $14.5 (b) Entergy Louisiana FTRs Purchased power expense $3.3 (b) Entergy Mississippi FTRs Purchased power expense $1.6 (b) Entergy New Orleans FTRs Purchased power expense ($1.4) (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 : Temporary cash investments $64.8 $— $— $64.8 Securitization recovery trust account 27.9 — — 27.9 FTRs — — 0.9 0.9 $92.7 $— $0.9 $93.6 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 March 31, 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 Gains (losses) included as a regulatory liability/asset 3.6 5.3 (0.7 ) (0.4 ) 0.2 Settlements (7.8 ) (10.5 ) (0.8 ) (0.5 ) (1.5 ) Balance as of March 31, $3.7 $3.3 $0.9 $0.6 $0.9 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 March 31, 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 Gains (losses) included as a regulatory liability/asset 15.0 (2.2 ) 0.8 (1.1 ) (10.3 ) Settlements (15.1 ) (14.5 ) (3.3 ) (1.6 ) 1.4 Balance as of March 31, $0.6 $8.8 $0.9 $1.4 $3.4
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 $255.0 $— $— $255.0 Decommissioning trust funds (a): Equity securities 2.1 — — 2.1 Debt securities 232.6 58.8 — 291.4 Common trusts (b) 426.3 $489.7 $58.8 $— $974.8 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)	3 Months Ended
	Mar. 31, 2016
Securities Held	The securities held as of March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,203 $1,638 $1 Debt Securities 2,249 78 4 Total $5,452 $1,716 $5 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $38 $1 $196 $2 More than 12 months — — 73 2 Total $38 $1 $269 $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 $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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $98 $77 1 year - 5 years 855 857 5 years - 10 years 711 704 10 years - 15 years 144 124 15 years - 20 years 58 50 20 years+ 383 343 Total $2,249 $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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $474.3 $238.5 $0.2 Debt Securities 311.2 9.5 0.8 Total $785.5 $248.0 $1.0 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $7.3 $0.2 $18.1 $0.4 More than 12 months — — 11.3 0.4 Total $7.3 $0.2 $29.4 $0.8 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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $3.7 $1.8 1 year - 5 years 142.0 145.2 5 years - 10 years 138.4 138.5 10 years - 15 years 7.5 2.4 15 years - 20 years 2.1 2.0 20 years+ 17.5 14.0 Total $311.2 $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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $643.0 $289.3 $0.1 Debt Securities 422.2 19.0 0.8 Total $1,065.2 $308.3 $0.9 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8.6 $0.1 $24.0 $0.3 More than 12 months — — 11.0 0.5 Total $8.6 $0.1 $35.0 $0.8 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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $31.9 $27.1 1 year - 5 years 114.8 124.0 5 years - 10 years 121.2 114.3 10 years - 15 years 43.6 39.3 15 years - 20 years 29.7 26.5 20 years+ 81.0 78.7 Total $422.2 $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 March 31, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $428.4 $182.7 $0.1 Debt Securities 291.4 5.5 0.4 Total $719.8 $188.2 $0.5 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 March 31, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $3.9 $0.1 $45.8 $0.3 More than 12 months — — 2.4 0.1 Total $3.9 $0.1 $48.2 $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 $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 March 31, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $4.6 $2.0 1 year - 5 years 180.9 181.2 5 years - 10 years 73.3 63.0 10 years - 15 years 4.5 4.4 15 years - 20 years 1.5 1.6 20 years+ 26.6 25.6 Total $291.4 $277.8

Commitments and Contingencies C

Commitments and Contingencies Commitments And Contingencies (Narrative) (Details) (Details) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2016USD ($)MW	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Incremental NRC Inspection Costs	$ 19.6		$ 53
Entergy Arkansas [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Expected NRC inspection costs excluding remediation and response costs		$ 50
Entergy Wholesale Commodities [Member] | Pilgrim [Member]
Regulatory Assets [Line Items]
Incremental NRC Inspection Costs	5
Entergy Wholesale Commodities [Member] | Minimum [Member] | Pilgrim [Member]
Regulatory Assets [Line Items]
Expected NRC inspection costs	45
Entergy Wholesale Commodities [Member] | Maximum [Member] | Pilgrim [Member]
Regulatory Assets [Line Items]
Expected NRC inspection costs	$ 60
Entergy Wholesale Commodities [Member] | Subsequent Event [Member] | Pilgrim [Member]
Regulatory Assets [Line Items]
Expected NRC inspection costs		$ 30
Pilgrim [Member]
Regulatory Assets [Line Items]
Capacity Supply Obligations in ISO New England | MW	677

Rate And Regulatory Matters (Na

Rate And Regulatory Matters (Narrative) (Details) $ in Thousands	1 Months Ended											3 Months Ended
	Apr. 30, 2016USD ($)	Mar. 31, 2016USD ($)	Feb. 29, 2016USD ($)	Jan. 31, 2016	Dec. 31, 2015USD ($)	Nov. 30, 2015USD ($)	Sep. 30, 2015USD ($)	Jul. 31, 2015USD ($)	Apr. 30, 2015USD ($)	Aug. 31, 2013	Jan. 31, 2013USD ($)intervenor	Mar. 31, 2016USD ($)	Mar. 31, 2015USD ($)	May. 31, 2015USD ($)
Commitments and Contingencies [Abstract]
Deferred Fuel Cost		$ 28,296			$ 0							$ 28,296
Payments to Acquire Property, Plant, and Equipment												(947,778)	$ 0
Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Refund to customers per LPSC Staff January 2013 audit report											$ 1,900
Realignment of the recovery from Entergy Louisiana's fuel adjustment clause to base rates per LPSC January 2013 audit report											$ 1,000
Number of Parties That Intervened in LPSC Proceeding | intervenor											2
Number of Intervenors | intervenor											1
Commitments and Contingencies [Abstract]
LPSC staff recommended fuel refund including interest		8,600
Amount of LPSC Recommended Realignment of Fuel Costs to Base Rates		12,700
Payments to Acquire Property, Plant, and Equipment		(474,000)										(473,888)	0
Earned return on common equity				10.22%
Estimated costs at completion for Ninemile 6 project								$ 648,000
Decrease in estimated costs at completion for Ninemile 6 project								76,000
Entergy Mississippi [Member]
Commitments and Contingencies [Abstract]
Rate Increase		$ 32,600
Deferred Fuel Over-Recovery Balance														$ 58,300
Under-Recovery Under Power Management Rider														$ 12,300
Net Over-Recovery of Rider Revenues								46,000
Projected Over-Recovery Energy Cost Recovery Rider			$ 68,000			$ 48,000
Earned return on common equity		9.96%
Entergy New Orleans [Member]
Commitments and Contingencies [Abstract]
Long-term payable due to Entergy Louisiana		$ 20,527			20,527							20,527
Payments to Acquire Property, Plant, and Equipment		(237,000)										(236,944)	0
Entergy Texas [Member]
Commitments and Contingencies [Abstract]
Public Utilities, Requested Rate Increase (Decrease), Amount							$ 13,000
System Agreement Bandwidth Refund Related to Calendar Year 2006 Production Costs								$ 10,900
Reduction in approved retail rate increase						2,000
Intervenor Recommended Disallowance Due to Load Growth Adjustment						$ 3,400
Entergy Texas [Member] | Subsequent Event [Member]
Commitments and Contingencies [Abstract]
Refund To Customers	$ 56,200
Refund for fuel cost recovery	41,800
System Agreement Bandwidth Refund Related to Calendar Year 2006-2008 Production Costs	$ 3,500
Entergy Arkansas [Member]
Commitments and Contingencies [Abstract]
Public Utilities Earned Return On Common Equity									10.20%
APSC and Intervener Recommended Revenue Requirement							$ 217,900
APSC and Intervener Recommended Return on Equity							9.65%
Net increase in revenues					133,000				$ 167,000
Rate Increase									$ 268,400
Deferred Fuel Cost		28,296			0							28,296
Public Utilities, Approved Rate Increase (Decrease), Amount					$ 225,000
Public Utilities, Approved Return on Equity, Percentage					9.75%
Basis Point Band					50.00%
Payments to Acquire Property, Plant, and Equipment		(237,000)										(236,947)	$ 0
Post-Fukushima Compliance Costs					$ 7,700
Flood Barrier Compliance Costs					$ 9,900
Reduction in approved retail rate increase			$ 5,000
Interim Base Rate Adjustment Surcharge Recovery		21,100
ALJ Recommended Percentage By Which Payments Be Reduced										20.00%
Liability Recorded Related to Estimated Payments Due Utility Operating Companies		87,000										87,000
Regulatory Asset Recorded to Represent Estimate of Recoverable Retail Portion of Costs		$ 75,000										$ 75,000

Equity (Narrative) (Details)

Equity (Narrative) (Details) - $ / shares	Apr. 06, 2016	Mar. 31, 2016	Mar. 31, 2015
Equity [Abstract]
Stock Options Excluded From Diluted Common Shares Outstanding Calculation		6,100,000	3,500,000
Common stock dividend (in dollars per share)		$ 0.85	$ 0.83
Parent Company [Member]
Equity [Abstract]
Shares, Issued		332,576
Subsequent Event [Member]
Equity [Abstract]
Common stock dividend (in dollars per share)	$ 0.85

Equity (Schedule Of Earnings Pe

Equity (Schedule Of Earnings Per Share, Basic And Diluted) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Basic earnings per share
Net income (loss) attributable to Entergy Corporation, Income	$ 229,966	$ 298,050
Net Income Attributable to Entergy Corporation, Shares	178,578,536	179,658,981
Net Income Attributable to Entergy Corporation, $/share	$ 1.29	$ 1.66
Average dilutive effect of:
Stock options, Shares	100,000	500,000
Stock options $/share	$ 0	$ (0.01)
Restricted stock, Shares	300,000	300,000
Restricted stock $/share	$ (0.01)	$ 0
Diluted earnings per share, Shares	178,976,380	180,480,523
Diluted earnings per share $/share	$ 1.28	$ 1.65

Equity (Accumulated Other Compr

Equity (Accumulated Other Comprehensive Income (Loss))(Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	$ 8,951	$ (42,307)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	115,055	(8,776)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(94,214)	(8,654)
Other comprehensive income (loss)	20,841	(17,430)
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	29,792	(59,737)
Foreign Currency Translation [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	2,028	2,669
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(284)	(551)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	0	0
Other comprehensive income (loss)	(284)	(551)
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	1,744	2,118
Net Unrealized Investment Gains [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	367,557	426,695
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	25,032	12,658
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(1,963)	(8,655)
Other comprehensive income (loss)	23,069	4,003
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	390,626	430,698
Pension And Other Postretirement Liabilities [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	(466,604)	(569,789)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0	13
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	7,562	8,435
Other comprehensive income (loss)	7,562	8,448
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	(459,042)	(561,341)
Cash Flow Hedges Net Unrealized Gain [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	105,970	98,118
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	90,307	(20,896)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(99,813)	(8,434)
Other comprehensive income (loss)	(9,506)	(29,330)
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	96,464	68,788
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)	(263)	380
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	(56,675)
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	(56,412)	(79,223)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(263)	380
Other comprehensive income (loss)	(263)	380
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	$ (56,675)	$ (78,843)

Equity (Reclassification out of

Equity (Reclassification out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Competitive Energy Revenue		$ 522,079	$ 642,590
Other Nonoperating Income (Expense)		(10,587)	(9,020)
INCOME BEFORE INCOME TAXES		375,187	453,400
Income taxes (benefits)		(139,945)	(150,471)
Consolidated net income	[1]	235,242	302,929
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Consolidated net income		94,214	8,654
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		1,963	8,655
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		153,958	13,522
Other Nonoperating Income (Expense)		(400)	(546)
INCOME BEFORE INCOME TAXES		153,558	12,976
Income taxes (benefits)		(53,745)	(4,542)
Consolidated net income		99,813	8,434
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)		3,850	16,970
Income taxes (benefits)		(1,887)	(8,315)
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]
Amortization of prior-service credit		7,355	5,986
Amortization of loss		(15,175)	(17,588)
INCOME BEFORE INCOME TAXES		(7,820)	(11,602)
Income taxes (benefits)		258	3,167
Consolidated net income		(7,562)	(8,435)
Entergy Louisiana [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Nonoperating Income (Expense)		(3,745)	(200)
INCOME BEFORE INCOME TAXES		161,348	168,911
Income taxes (benefits)		(49,742)	(42,802)
Consolidated net income		111,606	126,109
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	1,867
Amortization of loss		(1,569)	(2,535)
INCOME BEFORE INCOME TAXES		378	(668)
Income taxes (benefits)		(115)	288
Consolidated net income		$ 263	$ (380)
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $5.3 million and $3.2 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Revolving Credit Facilities, 36

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Narrative) (Details) - USD ($) $ in Thousands		1 Months Ended			3 Months Ended
		Apr. 30, 2016	Mar. 31, 2016	Jan. 31, 2016	Mar. 31, 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%
Letters of Credit Outstanding, Amount			$ 400		$ 400
Line of credit facility, commitment fee percentage					0.275%
Amount Drawn/ Outstanding			616,000		$ 616,000
Commercial Paper program limit			1,500,000		1,500,000
Commercial Paper Amount Outstanding			$ 578,000		$ 578,000
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			2.35%		2.35%
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%
Consolidated debt ratio			65.00%		65.00%
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%
Issuance Of Debt				$ 325,000
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 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%
Consolidated debt ratio			65.00%		65.00%
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%		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%		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] | 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%		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%		3.50%
Issuance Of Debt			$ 115,000
Entergy Mississippi [Member]
Debt Instrument [Line Items]
Letters of credit posted to cover derivative exposure			400		$ 400
Authorized Short Term Borrowings			175,000		175,000
Letters of Credit Outstanding, Amount			$ 400		$ 400
Consolidated debt ratio			65.00%		65.00%
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%
Consolidated debt ratio			65.00%		65.00%
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%		2.55%
Issuance Of Debt			$ 125,000
System Energy [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings			200,000		$ 200,000
Entergy Nuclear Vermont Yankee [Member]
Debt Instrument [Line Items]
Amount of Facility			100,000		$ 100,000
Line of credit facility, commitment fee percentage					0.25%
Amount Drawn/ Outstanding			61,000		$ 61,000
Line of Credit Facility, Interest Rate During Period					2.20%
Uncommitted Credit Facility			85,000		$ 85,000
Uncommitted Line of Credit Facility Interest Rate During Period					2.18%
Entergy New Orleans [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings			$ 100,000		$ 100,000
Consolidated debt ratio			65.00%		65.00%
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%		5.50%
Issuance Of Debt			$ 110,000
System Energy VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding			$ 111,000		$ 111,000
Line of credit facility commitment fee as a percentage of undrawn commitment amount					0.125%
Consolidated debt ratio of total capitalization					70.00%
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			$ 0		$ 0
Line of credit facility commitment fee as a percentage of undrawn commitment amount					0.125%
Consolidated debt ratio of total capitalization					70.00%
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%
Consolidated debt ratio of total capitalization					70.00%
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%		3.30%
Redemption of debt instrument			$ 20,000
Entergy Louisiana Waterford VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding			$ 77,500		$ 77,500
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%
Minimum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment fee percentage					0.125%
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Amount of Facility	[1]		$ 150,000		$ 150,000
Letters of Credit Outstanding, Amount			0		0
Amount Drawn/ Outstanding			0		$ 0
Line of Credit Facility, Interest Rate During Period	[2]				1.68%
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Amount of Facility	[3]		150,000		$ 150,000
Letters of Credit Outstanding, Amount			1,300		1,300
Amount Drawn/ Outstanding			$ 0		$ 0
Line of Credit Facility, Interest Rate During Period	[2]				1.93%
Subsequent Event [Member] | Entergy Louisiana [Member] | Pollution Control Revenue Bonds [Member]
Debt Instrument [Line Items]
Redemption of debt instrument		$ 198,680
[1]	The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility.
[2]	The interest rate is the rate as of March 31, 2016 that would most likely apply to outstanding borrowings under the facility.
[3]	The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.

Revolving Credit Facilities, 37

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	Mar. 31, 2016USD ($)
Summary of the borrowings outstanding and capacity available under the facility
Capacity	$ 3,500
Amount Drawn/ Outstanding	616
Letters of Credit	7
Capacity Available	$ 2,877

Revolving Credit Facilities, 38

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Credit Facilities) (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2016USD ($)
Amount of Facility	$ 3,500,000
Amount Drawn/ Outstanding	616,000
Letters of Credit Outstanding, Amount	$ 400
Entergy Arkansas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Aug. 14, 2020
Amount of Facility	$ 150,000	[1]
Interest Rate	1.68%	[2]
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Arkansas [Member] | Credit Facility Of Twenty Million [Member]
Expiration Date	Apr. 30, 2016
Amount of Facility	$ 20,000	[3]
Interest Rate	1.93%	[2]
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, 2020
Amount of Facility	$ 350,000	[4]
Interest Rate	1.68%	[2]
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	3,100
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	$ 400
Entergy Mississippi [Member] | Credit Facility Of Thirty Seven Point Five Million [Member]
Expiration Date	May 31, 2016
Amount of Facility	$ 37,500	[5]
Interest Rate	1.93%	[2]
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Thirty Five Million [Member]
Expiration Date	May 31, 2016
Amount of Facility	$ 35,000	[5]
Interest Rate	1.93%	[2]
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Twenty Million [Member]
Expiration Date	May 31, 2016
Amount of Facility	$ 20,000	[5]
Interest Rate	1.93%	[2]
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Ten Million [Member]
Expiration Date	May 31, 2016
Amount of Facility	$ 10,000	[5]
Interest Rate	1.93%	[2]
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy New Orleans [Member] | Credit Facility Of Twenty Five Million [Member]
Expiration Date	Nov. 30, 2018
Amount of Facility	$ 25,000
Interest Rate	2.18%	[2]
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Texas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Aug. 14, 2020
Amount of Facility	$ 150,000	[6]
Interest Rate	1.93%	[2]
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 1,300
[1]	The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility.
[2]	The interest rate is the rate as of March 31, 2016 that would most likely apply to outstanding borrowings under the facility.
[3]	Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. The credit facility expired in April 2016. Entergy Arkansas plans to renew the credit facility.
[4]	The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility.
[5]	Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. Entergy Mississippi expects to renew its credit facilities prior to expiration.
[6]	The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.

Revolving Credit Facilities, 39

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	Mar. 31, 2016USD ($)
Entergy Arkansas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	$ 250
Borrowings	0
Entergy Louisiana [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	450
Borrowings	0
Entergy Mississippi [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	175
Borrowings	0
Entergy New Orleans [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	100
Borrowings	0
Entergy Texas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	0
System Energy [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	$ 0

Revolving Credit Facilities, 40

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	3 Months Ended
	Mar. 31, 2016USD ($)
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount Drawn/ Outstanding	$ 616
Entergy Arkansas VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Jun. 30, 2016
Amount of Facility	$ 85
Amount Drawn/ Outstanding	$ 0
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.125%
System Energy VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Jun. 30, 2016
Amount of Facility	$ 125
Weighted Average Interest Rate on Borrowings	2.01%	[1]
Amount Drawn/ Outstanding	$ 111
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.125%
Entergy Louisiana River Bend VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Jun. 30, 2016
Amount of Facility	$ 100
Amount Drawn/ Outstanding	$ 0
Entergy Louisiana Waterford VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Jun. 30, 2016
Amount of Facility	$ 90
Weighted Average Interest Rate on Borrowings	1.86%	[1]
Amount Drawn/ Outstanding	$ 77.5
[1]	(a)Prior to expiration, the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy each plan to renew its credit facility.

Revolving Credit Facilities, 41

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Notes Payable By Variable Interest Entities) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2016USD ($)
Entergy Arkansas VIE [Member]
Notes payable by variable interest entities
Consolidated Debt Ratio Of Capitalization	70.00%
Entergy Louisiana VIE [Member]
Notes payable by variable interest entities
Consolidated Debt Ratio Of Capitalization	70.00%
System Energy VIE [Member]
Notes payable by variable interest entities
Consolidated Debt Ratio Of Capitalization	70.00%
Three Point Two Three Percent Series J Notes Due July Two Thousand Sixteen [Member] | Entergy Arkansas VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.23%
Amount	$ 55
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, 42

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	Mar. 31, 2016		Dec. 31, 2015
Short-term Debt [Line Items]
Long-term Debt, Fair Value	$ 14,811,845	[1],[2]	$ 13,578,511	[3],[4]
Long-term Debt, Book Value	14,296,872		13,325,930
Notes payable to power authority	35,000		35,000
Entergy Arkansas [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	2,726,079	[1],[2]	2,498,108	[3],[4]
Long-term Debt, Book Value	2,777,649		2,629,839
Long term DOE obligations	181,000		181,000
Entergy Louisiana [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	5,967,996	[1],[2]	5,018,786	[3],[4]
Long-term Debt, Book Value	5,620,234		4,836,162
Capital Lease Obligations	56,000		109,000
Entergy Mississippi [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	1,100,469	[1],[2]	1,087,326	[3],[4]
Long-term Debt, Book Value	1,045,430		1,045,085
Entergy New Orleans [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	443,145	[1],[2]	351,040	[3],[4]
Long-term Debt, Book Value	449,892		342,880
Entergy Texas [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	1,702,601	[1],[2]	1,590,616	[3],[4]
Long-term Debt, Book Value	1,552,741		1,451,967
System Energy [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	550,080	[1],[2]	552,762	[3],[4]
Long-term Debt, Book Value	572,742		572,667
Capital Lease Obligations	$ 34,000		$ 34,000
[1]	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.
[2]	The values exclude lease obligations of $56 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.
[3]	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.
[4]	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.

Revolving Credit Facilities, 43

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	Mar. 31, 2016USD ($)
Letters of Credit Outstanding, Amount	$ 0.4
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	0.4
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	$ 5.6
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	$ 4.4
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	$ 6.2
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	$ 7

Stock Based Compensation (Narra

Stock Based Compensation (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	Jan. 28, 2016	Jan. 31, 2016	Mar. 31, 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			7,562,576
Weighted-average exercise price of stock options outstanding (in dollars per share)			$ 84.06
Intrinsic value in the money stock options			$ 30.5
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
	Mar. 31, 2016	Mar. 31, 2015
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 1.1	$ 1.1
Tax benefit recognized in Entergy's net income	0.4	0.4
Compensation cost capitalized as part of fixed assets and inventory	$ 0.2	$ 0.2

Stock-Based Compensation (Fin46

Stock-Based Compensation (Financial Information For Other Equity Plans) (Details) - Parent Company [Member] - Restricted Stock Awards [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 8.4	$ 8.1
Tax benefit recognized in Entergy's net income	3.2	3.1
Compensation cost capitalized as part of fixed assets and inventory	$ 1.8	$ 1.5

Retirement And Other Postreti47

Retirement And Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Expected current year pension contributions	$ 88,200
Pension contributions made through Year To Date	387,500
Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Expected current year pension contributions	19,494
Pension contributions made through Year To Date	82,831
Remaining estimated pension contributions to be made in current year	63,337
Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Expected current year pension contributions	3,798
Pension contributions made through Year To Date	15,770
Remaining estimated pension contributions to be made in current year	11,972
Non-Qualified Pension Plans [Member] | Parent Company [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	4,300	$ 4,500
Non-Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	106	113
Non-Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	$ 127	$ 149

Retirement And Other Postreti48

Retirement And Other Postretirement Benefits (Components Of Qualified Net Pension Cost) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
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 (credit)	270	390
Amortization of loss	48,824	58,981
Defined Benefit Plan, Special Termination Benefits	0	76
Net other postretirement benefit cost	52,942	80,248
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
Interest cost on projected benefit obligation	13,055	15,471
Expected return on assets	(19,772)	(20,026)
Amortization of loss	10,936	13,564
Net other postretirement benefit cost	9,400	15,670
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
Interest cost on projected benefit obligation	14,870	17,367
Expected return on assets	(22,096)	(22,701)
Amortization of loss	11,946	14,951
Net other postretirement benefit cost	11,769	18,216
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
Interest cost on projected benefit obligation	3,811	4,502
Expected return on assets	(5,981)	(6,105)
Amortization of loss	2,985	3,724
Net other postretirement benefit cost	2,377	4,103
Pension Plans Defined Benefit [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	656	849
Interest cost on projected benefit obligation	1,814	2,108
Expected return on assets	(2,687)	(2,725)
Amortization of loss	1,615	2,013
Net other postretirement benefit cost	1,398	2,245
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
Interest cost on projected benefit obligation	3,557	4,354
Expected return on assets	(6,062)	(6,222)
Amortization of loss	2,340	3,238
Net other postretirement benefit cost	1,251	3,015
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
Interest cost on projected benefit obligation	2,992	3,493
Expected return on assets	(4,459)	(4,568)
Amortization of loss	2,604	3,264
Net other postretirement benefit cost	2,703	4,146
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	8,073	11,326
Interest cost on projected benefit obligation	14,083	17,984
Expected return on assets	(10,455)	(11,344)
Amortization of prior service cost (credit)	(11,373)	(9,320)
Amortization of loss	4,554	7,893
Net other postretirement benefit cost	4,882	16,539
Other Postretirement [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	978	1,739
Interest cost on projected benefit obligation	2,324	3,130
Expected return on assets	(4,464)	(4,798)
Amortization of prior service cost (credit)	(1,368)	(610)
Amortization of loss	1,064	1,339
Net other postretirement benefit cost	(1,466)	800
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,869	2,474
Interest cost on projected benefit obligation	3,260	4,078
Expected return on assets	0	0
Amortization of prior service cost (credit)	(1,947)	(1,867)
Amortization of loss	731	1,780
Net other postretirement benefit cost	3,913	6,465
Other Postretirement [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	386	507
Interest cost on projected benefit obligation	709	859
Expected return on assets	(1,379)	(1,542)
Amortization of prior service cost (credit)	(234)	(229)
Amortization of loss	223	215
Net other postretirement benefit cost	(295)	(190)
Other Postretirement [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	156	205
Interest cost on projected benefit obligation	448	652
Expected return on assets	(1,154)	(1,201)
Amortization of prior service cost (credit)	(186)	(177)
Amortization of loss	37	118
Net other postretirement benefit cost	(699)	(403)
Other Postretirement [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	398	500
Interest cost on projected benefit obligation	1,039	1,342
Expected return on assets	(2,394)	(2,588)
Amortization of prior service cost (credit)	(681)	(681)
Amortization of loss	537	685
Net other postretirement benefit cost	(1,101)	(742)
Other Postretirement [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	334	470
Interest cost on projected benefit obligation	529	628
Expected return on assets	(814)	(911)
Amortization of prior service cost (credit)	(393)	(366)
Amortization of loss	287	300
Net other postretirement benefit cost	(57)	121
Non-Qualified Pension Plans [Member] | Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	4,300	4,500
Non-Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	106	113
Non-Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	59	68
Non-Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	59	59
Non-Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	16	16
Non-Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	$ 127	$ 149

Retirement And Other Postreti49

Retirement And Other Postretirement Benefits (Expected Employer Contributions) (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2016USD ($)
Change in Plan Assets
Expected current year pension contributions	$ 88,200
Pension contributions made through Year To Date	387,500
Entergy Arkansas [Member]
Change in Plan Assets
Expected current year pension contributions	19,494
Pension contributions made through Year To Date	82,831
Remaining estimated pension contributions to be made in current year	63,337
Entergy Louisiana [Member]
Change in Plan Assets
Expected current year pension contributions	20,195
Pension contributions made through Year To Date	83,909
Remaining estimated pension contributions to be made in current year	63,714
Entergy Mississippi [Member]
Change in Plan Assets
Expected current year pension contributions	4,946
Pension contributions made through Year To Date	19,913
Remaining estimated pension contributions to be made in current year	14,967
Entergy New Orleans [Member]
Change in Plan Assets
Expected current year pension contributions	2,434
Pension contributions made through Year To Date	10,694
Remaining estimated pension contributions to be made in current year	8,260
Entergy Texas [Member]
Change in Plan Assets
Expected current year pension contributions	3,798
Pension contributions made through Year To Date	15,770
Remaining estimated pension contributions to be made in current year	11,972
System Energy [Member]
Change in Plan Assets
Expected current year pension contributions	4,613
Pension contributions made through Year To Date	20,206
Remaining estimated pension contributions to be made in current year	$ 15,593

Retirement And Other Postreti50

Retirement And Other Postretirement Benefits (Reclassification Out Of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	$ 7,355	$ 5,986
Amortization of loss	(15,175)	(17,588)
Total	(7,820)	(11,602)
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,947	1,867
Amortization of loss	(1,569)	(2,535)
Total	378	(668)
Pension Plans Defined Benefit [Member] | Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(270)	(389)
Amortization of loss	(12,482)	(12,627)
Total	(12,752)	(13,016)
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0
Amortization of loss	(836)	(751)
Total	(836)	(751)
Other Postretirement [Member] | Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	7,738	6,482
Amortization of loss	(2,063)	(4,409)
Total	5,675	2,073
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,947	1,867
Amortization of loss	(731)	(1,779)
Total	1,216	88
Non-Qualified Pension Plans [Member] | Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(113)	(107)
Amortization of loss	(630)	(552)
Total	(743)	(659)
Non-Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0
Amortization of loss	(2)	(5)
Total	$ (2)	$ (5)

Business Segment Information (S

Business Segment Information (Segment Financial Information) (Details) - USD ($)		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Segment Financial Information
Operating revenues		$ 2,609,852,000	$ 2,920,090,000
Income taxes (benefits)		139,945,000	150,471,000
Consolidated net income	[1]	235,242,000	302,929,000
Assets		45,933,882,000		$ 44,647,681,000
Utility [Member]
Segment Financial Information
Operating revenues		2,087,793,000	2,277,510,000
Income taxes (benefits)		107,836,000	91,251,000
Consolidated net income		199,651,000	227,750,000
Entergy Wholesale Commodities [Member]
Segment Financial Information
Operating revenues		522,079,000	642,590,000
Income taxes (benefits)		52,314,000	70,190,000
Consolidated net income		79,557,000	123,432,000
All Other [Member]
Segment Financial Information
Operating revenues		0	0
Income taxes (benefits)		(20,205,000)	(10,970,000)
Consolidated net income		(12,067,000)	(16,354,000)
Eliminations [Member]
Segment Financial Information
Operating revenues		(20,000)	(10,000)
Income taxes (benefits)		0	0
Consolidated net income		$ (31,899,000)	$ (31,899,000)
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $5.3 million and $3.2 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Risk Management and Fair Valu52

Risk Management and Fair Values (Narrative) (Details) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2016USD ($)MMBTUMWhcounterparty	Mar. 31, 2015USD ($)	Dec. 31, 2015USD ($)counterparty
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount	$ 0.4
Cash collateral posted			$ 9
Derivative, Collateral, Obligation to Return Cash	66		$ 68
Cash flow hedges relating to power sales as part of net unrealized gains	152
Reclassified from accumulated other comprehensive income (OCI) to operating revenues	$ 134
Number of Derivative Contract Counterparties in a Liability Position | counterparty	0		2
Maturity of cash flow hedges, Tax	$ 54	$ 5
Maximum length of time over which Company is currently hedging the variability in future cash flows for forecasted power transactions, years	2 years
Planned generation sold forward from non utility nuclear power plants for the remainder of the period	88.00%
Planned Generation Sold Forward under financial derivatives	60.00%
Total planned generation for remainder of the period | MWh	25,000,000
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	57,500,000
Total volume of fixed transmission rights outstanding | MWh	18,305,000
Change in cash flow hedges due to ineffectiveness	$ (1)	(1)
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	$ 6	$ (87)
Entergy Arkansas [Member]
Risk Management and Fair Values [Abstract]
Total volume of fixed transmission rights outstanding | MWh	3,894,000
Entergy Louisiana [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	46,330,000
Total volume of fixed transmission rights outstanding | MWh	8,385,000
Entergy Mississippi [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount	$ 0.4
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	11,170,000
Total volume of fixed transmission rights outstanding | MWh	2,436,000
Entergy New Orleans [Member]
Risk Management and Fair Values [Abstract]
Total volume of fixed transmission rights outstanding | MWh	1,398,000
Entergy Texas [Member]
Risk Management and Fair Values [Abstract]
Total volume of fixed transmission rights outstanding | MWh	2,086,000

Risk Management and Fair Valu53

Risk Management and Fair Values (Fair Values Of Derivative Instruments) (Details) - USD ($) $ in Millions		Mar. 31, 2016		Dec. 31, 2015
Assets:
Derivative asset as hedging instrument offset		$ (66)		$ (68)
Other Non-Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	[1]	1		2
Derivative liability as hedging instrument offset	[2]	(1)		(2)
Derivative Liability	[3],[4]	0		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	[1]	20		17
Derivative asset as hedging instrument offset	[2]	(1)		(2)
Derivative Asset	[3],[4]	19		15
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	[1]	120		173
Derivative asset as hedging instrument offset	[2]	(26)		(34)
Derivative Asset	[3],[4]	94		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	[1]	94		54
Derivative asset as hedging instrument offset	[2]	(24)		(13)
Derivative Asset	[3],[4]	70		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	[1]	9		24
Derivative asset as hedging instrument offset	[2]			(1)
Derivative Asset	[3],[4]	9		23
Other Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	[1]	1		14
Derivative liability as hedging instrument offset	[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, Fair Value, Gross Liability	[1]	49		38
Derivative liability as hedging instrument offset	[2]	(49)		(32)
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, Fair Value, Gross Liability	[1]	9		9
Derivative liability as hedging instrument offset		0	[1]	0	[2]
Derivative Liability	[3],[4]	9		9
Entergy Louisiana [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset		3.3		8.5
Entergy Louisiana [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		7.6		7
Entergy Mississippi [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset		0.9		2.4
Entergy Mississippi [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		1.8		1.3
Entergy New Orleans [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset		0.6		1.5
Entergy New Orleans [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability				0.5
Entergy Arkansas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset		3.7		7.9
Entergy Texas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset		$ 0.9		$ 2.2
[1]	Represents the gross amounts of recognized assets/liabilities
[2]	Represents the netting of fair value balances with the same counterparty
[3]	Excludes cash collateral in the amount of $9 million posted and $68 million held as of December 31, 2015. There was no cash collateral required to be posted as of March 31, 2016. Also excludes letters of credit in the amount of $0.4 million posted and $66 million held as of March 31, 2016.
[4]	Represents the net amounts of assets /liabilities presented on the Entergy Consolidated Balance Sheets

Risk Management and Fair Valu54

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
	Mar. 31, 2016	Mar. 31, 2015
Effect of Derivative instruments designated as cash flow hedges on consolidated statements of income
Amount of gain (loss) recognized in AOCI (effective portion)	$ 139	$ (32)
Amount of gain reclassified from accumulated OCI into income (effective portion)	$ 154	$ 14

Risk Management and Fair Valu55

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
	Mar. 31, 2016	Mar. 31, 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	$ 25	$ 4
Amount of gain (loss) recorded in income	0	(34)
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
Amount of gain (loss) recorded in income	(24)	(19)
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
Amount of gain (loss) recorded in income	21	33
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	7.8	15.1
Entergy Louisiana [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	(19.3)	(16)
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	10.5	14.5
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	(4.1)	(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	0.8	3.3
Entergy New Orleans [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	(0.5)	(0.5)
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	0.5	1.6
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	$ 1.5	$ (1.4)

Risk Management and Fair Valu56

Risk Management and Fair Values (Assets And Liabilities At Fair Value On A Recurring Basis) (Details) - USD ($) $ in Thousands		Mar. 31, 2016	Dec. 31, 2015
Assets at fair value on a recurring basis
Assets other than temporary cash investments		$ 5,452,000	$ 5,350,000
Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		1,010,000	1,287,000
Assets Held-in-trust, Current		197,000
Liabilities at fair value on a recurring basis
Total			15,000
Assets, Fair Value Disclosure		7,357,000	7,330,000
Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		9,000	9,000
Power Contracts Liabilities [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			6,000
Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	446,000	468,000
Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	2,249,000	2,155,000
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]	2,757,000	2,727,000
Power Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		183,000	195,000
Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		454,000	425,000
Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		52,000	50,000
Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		9,000	23,000
Fair Value Inputs Level 1 [Member]
Assets at fair value on a recurring basis
Temporary cash investments		1,010,000	1,287,000
Assets Held-in-trust, Current		197,000
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		9,000
Total			9,000
Assets, Fair Value Disclosure		3,219,000	3,291,000
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			9,000
Fair Value Inputs Level 1 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
Fair Value Inputs Level 1 [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	446,000	468,000
Fair Value Inputs Level 1 [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	1,060,000	1,061,000
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		454,000	425,000
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		52,000	50,000
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
Assets Held-in-trust, Current		0
Liabilities at fair value on a recurring basis
Total			0
Assets, Fair Value Disclosure		1,189,000	1,094,000
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		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]	1,189,000	1,094,000
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
Assets Held-in-trust, Current		0
Liabilities at fair value on a recurring basis
Total			6,000
Assets, Fair Value Disclosure		192,000	218,000
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Fair Value, Inputs, Level 3 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			6,000
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		183,000	195,000
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		9,000	23,000
Entergy Louisiana [Member]
Assets at fair value on a recurring basis
Assets Held-in-trust, Current		196,568	0
Assets other than temporary cash investments		1,065,200	1,042,300
Entergy Louisiana [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		100,000	34,800
Assets Held-in-trust, Current		196,600
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,678,700	1,379,200
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		7,600	7,000
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]	8,500	7,100
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]	422,200	409,900
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]	634,500	625,300
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		304,900	290,400
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		8,700	3,200
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		3,300	8,500
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		100,000	34,800
Assets Held-in-trust, Current		196,600
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		773,200	496,600
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		7,600	7,000
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]	8,500	7,100
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]	154,500	161,100
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		304,900	290,400
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		8,700	3,200
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
Assets Held-in-trust, Current		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		267,700	248,800
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]	267,700	248,800
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
Assets Held-in-trust, Current		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		3,300	8,500
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		3,300	8,500
Entergy Arkansas [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		785,500	771,300
Entergy Arkansas [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		13,400
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		829,500	795,600
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]	5,200	3,000
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]	311,200	303,900
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]	469,100	464,400
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		19,300	12,200
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		7,600	4,200
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		3,700	7,900
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		13,400
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		147,800	129,900
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]	5,200	3,000
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]	102,300	110,500
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		19,300	12,200
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		7,600	4,200
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]
Assets at fair value on a recurring basis
Temporary cash investments		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		208,900	193,400
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]	208,900	193,400
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]
Assets at fair value on a recurring basis
Temporary cash investments		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		3,700	7,900
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		3,700	7,900
Entergy Mississippi [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		112,700	144,200
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		155,400	188,300
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		1,800	1,300
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		41,800	41,700
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		900	2,400
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		112,700	144,200
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		154,500	185,900
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		1,800	1,300
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		41,800	41,700
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		900	2,400
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		900	2,400
Entergy New Orleans [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		5,300	87,800
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		101,500	174,900
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			500
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		88,200	81,000
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		7,400	4,600
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		600	1,500
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		5,300	87,800
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		100,900	173,400
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			500
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		88,200	81,000
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		7,400	4,600
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		600	1,500
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		600	1,500
Entergy Texas [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		64,800
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		93,600	40,400
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		27,900	38,200
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		900	2,200
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		64,800
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		92,700	38,200
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		27,900	38,200
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]
Assets at fair value on a recurring basis
Temporary cash investments		0
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]
Assets at fair value on a recurring basis
Temporary cash investments		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		900	2,200
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		900	2,200
System Energy [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		719,800	701,500
System Energy [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		255,000	222,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		974,800	923,500
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]	2,100	1,800
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]	291,400	277,800
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]	426,300	421,900
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		255,000	222,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		489,700	442,400
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]	2,100	1,800
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]	232,600	218,600
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		58,800	59,200
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]	58,800	59,200
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 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 (NAV) 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 NAV and trades settle at a later date.
[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 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 (NAV) 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 NAV and trades settle at a later date.

Risk Management and Fair Valu57

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
	Mar. 31, 2016	Mar. 31, 2015
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	$ 189	$ 215
Total gains (losses) for the period (a)	0	(35)
Unrealized losses included in OCI	139	(26)
Included as a regulatory liability/asset	0	0
Purchases	0	10
Settlements	(145)	(19)
Balance as of March 31,	183	145
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	23	47
Total gains (losses) for the period (a)	0	0
Unrealized losses included in OCI	0	0
Included as a regulatory liability/asset	7	1
Purchases	0	0
Settlements	(21)	(33)
Balance as of March 31,	9	15
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	7.9	0.7
Unrealized gains included as a regulatory liability/asset	3.6	15
Settlements	(7.8)	(15.1)
Balance as of March 31,	3.7	0.6
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	8.5	25.5
Unrealized gains included as a regulatory liability/asset	5.3	(2.2)
Settlements	(10.5)	(14.5)
Balance as of March 31,	3.3	8.8
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	2.4	3.4
Unrealized gains included as a regulatory liability/asset	(0.7)	0.8
Settlements	(0.8)	(3.3)
Balance as of March 31,	0.9	0.9
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	1.5	4.1
Unrealized gains included as a regulatory liability/asset	(0.4)	(1.1)
Settlements	(0.5)	(1.6)
Balance as of March 31,	0.6	1.4
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	2.2	12.3
Unrealized gains included as a regulatory liability/asset	0.2	(10.3)
Settlements	(1.5)	1.4
Balance as of March 31,	$ 0.9	$ 3.4

Risk Management and Fair Valu58

Risk Management and Fair Values (Schedules Of Valuation Techniques) (Details) - Parent Company [Member] $ in Millions	Mar. 31, 2016USD ($)
Range From Average Percentage for Electricity Options	30.00%
Range from Average Percentage for Fair Value of Electricity Swaps	3.00%
Effect of Significant Unobservable Inputs on Fair Value of Electricity Swaps	$ 7
Effect of Significant Unobservable Inputs on Fair Value of Electricity Options	10
Fair Value of Electricity Options	34
Fair Value of Electricity Swaps	$ 149

Decommissioning Trust Funds (Na

Decommissioning Trust Funds (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts	$ 361,000		$ 342,000
Amortized cost of debt securities	$ 2,183,000		2,124,000
Average coupon rate of debt securities	3.20%
Average duration of debt securities, years	5 years 10 months 2 days
Average maturity of debt securities, years	8 years 10 months 28 days
Proceeds from the dispositions of debt securities	$ 729,000	$ 493,000
Gains from dispositions of debt securities, gross	10,000	26,000
Losses from dispositions of debt securities, gross	3,000	2,000
Entergy Arkansas [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 302,000		301,800
Average coupon rate of debt securities	2.58%
Average duration of debt securities, years	5 years 3 months
Average maturity of debt securities, years	6 years 1 month 28 days
Proceeds from the dispositions of debt securities	$ 58,600	81,900
Gains from dispositions of debt securities, gross	800	5,100
Losses from dispositions of debt securities, gross	$ 100	0
Entergy Louisiana [Member]
Decommissioning Trust Funds [Abstract]
Percentage Interest in River Bend	30.00%
Amortized cost of debt securities	$ 407,000		399,200
Average coupon rate of debt securities	3.89%
Average duration of debt securities, years	5 years 6 months 16 days
Average maturity of debt securities, years	10 years 2 months 28 days
Proceeds from the dispositions of debt securities	$ 53,800	25,600
Gains from dispositions of debt securities, gross	900	1,300
Losses from dispositions of debt securities, gross	100	10
System Energy [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 286,900		$ 270,700
Average coupon rate of debt securities	1.93%
Average duration of debt securities, years	5 years 7 days
Average maturity of debt securities, years	6 years 4 months 14 days
Proceeds from the dispositions of debt securities	$ 188,500	78,400
Gains from dispositions of debt securities, gross	1,600	400
Losses from dispositions of debt securities, gross	$ 300	$ 100

Decommissioning Trust Funds (Se

Decommissioning Trust Funds (Securities Held) (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Schedule of Available-for-sale Securities [Line Items]
Fair Value	$ 5,452	$ 5,350
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	1,716	1,437
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	5	19
Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	3,203	3,195
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	1,638	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	2,249	2,155
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	78	41
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	4	17
Entergy Arkansas [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	785.5	771.3
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	248	238.5
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	1	2.4
Entergy Arkansas [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	474.3	467.4
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	238.5	234.4
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.2	0.2
Entergy Arkansas [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	311.2	303.9
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	9.5	4.1
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.8	2.2
Entergy Louisiana [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	1,065.2	1,042.3
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	308.3	296.9
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.9	2.6
Entergy Louisiana [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	643	632.4
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	289.3	283.7
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.1	0.2
Entergy Louisiana [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	422.2	409.9
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	19	13.2
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.8	2.4
System Energy [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	719.8	701.5
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	188.2	181.4
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.5	2.6
System Energy [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	428.4	423.7
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	182.7	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	291.4	277.8
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	5.5	2.2
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	$ 0.4	$ 2.3

Decommissioning Trust Funds (Av

Decommissioning Trust Funds (Available For Sale Securities Continuous Unrealized Loss Position Fair Value) (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	$ 38	$ 54
More than 12 months Fair Value	0	1
Total Fair Value	38	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	196	1,031
More than 12 months Fair Value	73	61
Total Fair Value	269	1,092
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	2	15
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	2	2
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	4	17
Entergy Arkansas [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	7.3	7.8
More than 12 months Fair Value	0	0
Total Fair Value	7.3	7.8
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0.2	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	0.2	0.2
Entergy Arkansas [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	18.1	111.4
More than 12 months Fair Value	11.3	18.5
Total Fair Value	29.4	129.9
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0.4	1.7
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.4	0.5
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	0.8	2.2
Entergy Louisiana [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	8.6	9.4
More than 12 months Fair Value	0	0
Total Fair Value	8.6	9.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0.1	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	0.1	0.2
Entergy Louisiana [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	24	124
More than 12 months Fair Value	11	7.4
Total Fair Value	35	131.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0.3	2
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.5	0.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	0.8	2.4
System Energy [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	3.9	8.3
More than 12 months Fair Value	0	0.9
Total Fair Value	3.9	9.2
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0.1	0.2
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0	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	45.8	200.4
More than 12 months Fair Value	2.4	5
Total Fair Value	48.2	205.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0.3	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	$ 0.4	$ 2.3

Decommissioning Trust Funds (Fa

Decommissioning Trust Funds (Fair Value Of Debt Securities By Contractual Maturities) (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Fair value of debt securities by contractual maturities
Less than 1 year	$ 98	$ 77
1 year - 5 years	855	857
5 years - 10 years	711	704
10 years - 15 years	144	124
15 years - 20 years	58	50
20 years+	383	343
Total	2,249	2,155
Entergy Arkansas [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	3.7	1.8
1 year - 5 years	142	145.2
5 years - 10 years	138.4	138.5
10 years - 15 years	7.5	2.4
15 years - 20 years	2.1	2
20 years+	17.5	14
Total	311.2	303.9
Entergy Louisiana [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	31.9	27.1
1 year - 5 years	114.8	124
5 years - 10 years	121.2	114.3
10 years - 15 years	43.6	39.3
15 years - 20 years	29.7	26.5
20 years+	81	78.7
Total	422.2	409.9
System Energy [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	4.6	2
1 year - 5 years	180.9	181.2
5 years - 10 years	73.3	63
10 years - 15 years	4.5	4.4
15 years - 20 years	1.5	1.6
20 years+	26.6	25.6
Total	$ 291.4	$ 277.8

Income Taxes Income Taxes (Narr

Income Taxes Income Taxes (Narrative) (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Regulatory Liability, Noncurrent	$ 1,433,632	$ 1,414,898
Entergy Arkansas [Member]
Regulatory Liability, Noncurrent	257,879	242,913
Entergy Louisiana [Member]
Regulatory Liability, Noncurrent	817,625	818,623
System Energy [Member]
Regulatory Liability, Noncurrent	$ 344,950	$ 337,424

Property, Plant, And Equipment

Property, Plant, And Equipment (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Construction expenditures in accounts payable	$ 172,000	$ 172,000		$ 234,000
Impairment of Long-Lived Assets Held-for-use		7,361	$ 0
Asset Write-Offs, Impairments, And Related Charges		7,361	$ 0
Entergy Arkansas [Member]
Construction expenditures in accounts payable	29,300	29,300		43,000
Entergy Louisiana [Member]
Construction expenditures in accounts payable	40,500	40,500		68,600
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	2,500	2,500		11,400
Entergy New Orleans [Member]
Construction expenditures in accounts payable	400	400		1,500
Entergy Texas [Member]
Construction expenditures in accounts payable	17,300	17,300		33,100
System Energy [Member]
Construction expenditures in accounts payable	$ 24,700	$ 24,700		$ 6,800

Variable Interest Entities (Nar

Variable Interest Entities (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Waterford Three [Member] | Entergy Louisiana [Member]
Variable Interest Entity [Line Items]
Payments on lease, including interest	$ 9.2	$ 21
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	$ 37.6
Percentage in power plant owned by VIE	11.50%

Acquisitions Acquisitions (Narr

Acquisitions Acquisitions (Narrative) (Details) $ in Thousands	1 Months Ended	3 Months Ended
	Mar. 31, 2016USD ($)MW	Mar. 31, 2016USD ($)MW	Mar. 31, 2015USD ($)
Payments to Acquire Property, Plant, and Equipment		$ (947,778)	$ 0
Union Power Station [Member]
Capacity Per Power Block | MW	495	495
Payments to Acquire Property, Plant, and Equipment	$ (948,000)
Capacity Of Power Plant Unit | MW	1,980
Entergy Arkansas [Member]
Payments to Acquire Property, Plant, and Equipment	$ (237,000)	$ (236,947)	0
Entergy Arkansas [Member] | Union Power Station [Member]
Percentage of Undivided Ownership Interest	25.00%	25.00%
Payments to Acquire Property, Plant, and Equipment	$ (236,944)
Power Blocks Purchased	1	1
Entergy Louisiana [Member]
Payments to Acquire Property, Plant, and Equipment	$ (474,000)	$ (473,888)	0
Entergy Louisiana [Member] | Union Power Station [Member]
Percentage of Undivided Ownership Interest	50.00%	50.00%
Payments to Acquire Property, Plant, and Equipment	$ (473,888)
Power Blocks Purchased	2	2
Entergy New Orleans [Member]
Payments to Acquire Property, Plant, and Equipment	$ (237,000)	$ (236,944)	$ 0
Entergy New Orleans [Member] | Union Power Station [Member]
Percentage of Undivided Ownership Interest	25.00%	25.00%
Payments to Acquire Property, Plant, and Equipment	$ (236,944)
Power Blocks Purchased	1	1