Entergy Texas (ETI-P) 10-Q 4 Aug 16 2016 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2016	Jul. 29, 2016
Entity Registrant Name	ENTERGY CORP /DE/
Entity Central Index Key	65,984
Document Type	10-Q
Document Period End Date	Jun. 30, 2016
Amendment Flag	false
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q2
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		178,982,069
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		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016		Jun. 30, 2015
OPERATING REVENUES
Electric	$ 2,093,331	$ 2,246,148	$ 4,135,492		$ 4,464,137
Natural gas	25,121	27,777	70,734		87,288
Competitive businesses	344,110	439,306	866,189		1,081,896
TOTAL	2,462,562	2,713,231	5,072,415		5,633,321
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	381,465	549,702	886,432		1,180,156
Purchased power	242,672	322,929	504,996		664,951
Nuclear refueling outage expenses	47,045	67,129	98,276		131,998
Other operation and maintenance	759,258	827,872	1,491,174		1,597,983
Asset Write-Offs, Impairments, And Related Charges	6,969	0	14,329		0
Decommissioning	76,625	68,830	145,253		138,729
Taxes other than income taxes	149,249	156,378	299,027		313,901
Depreciation and amortization	335,668	340,354	669,939		672,340
Other regulatory charges (credits) - net	21,353	2,654	22,512		13,111
TOTAL	2,020,304	2,335,848	4,131,938		4,713,169
OPERATING INCOME	442,258	377,383	940,477		920,152
OTHER INCOME
Allowance for equity funds used during construction	13,860	11,974	32,792		23,712
Investment Income, Net	46,375	39,705	79,128		107,839
Miscellaneous - net	(8,377)	(15,743)	(18,963)		(24,764)
TOTAL	51,858	35,936	92,957		106,787
INTEREST EXPENSE
Interest expense	177,631	165,860	351,442		332,197
Allowance for borrowed funds used during construction	(7,132)	(6,044)	(16,813)		(12,161)
TOTAL	170,499	159,816	334,629		320,036
INCOME BEFORE INCOME TAXES	323,617	253,503	698,805		706,903
Income taxes	(248,973)	99,781	(109,027)		250,252
CONSOLIDATED NET INCOME	572,590	153,722	807,832	[1]	456,651	[1]
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	5,276	4,879	10,552		9,759
EARNINGS APPLICABLE TO COMMON STOCK	$ 567,314	$ 148,843	$ 797,280		$ 446,892
Earnings per average common share:
Basic (in dollars per share)	$ 3.17	$ 0.83	$ 4.46		$ 2.49
Diluted (in dollars per share)	3.16	0.83	4.45		2.48
Dividends declared per common share (in dollars per share)	$ 0.85	$ 0.83	$ 1.70		$ 1.66
Basic average number of common shares outstanding (in shares)	178,808,149	179,521,276	178,693,342		179,589,748
Diluted average number of common shares outstanding (in shares)	179,503,582	180,119,837	179,233,209		180,298,233
Entergy Arkansas [Member]
OPERATING REVENUES
Electric	$ 504,252	$ 551,809	$ 969,625		$ 1,063,062
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	88,022	145,315	168,959		250,187
Purchased power	49,714	80,671	111,518		180,485
Nuclear refueling outage expenses	14,981	13,443	30,050		25,506
Other operation and maintenance	173,909	169,365	326,815		329,910
Decommissioning	13,301	12,491	26,404		24,795
Taxes other than income taxes	22,961	22,980	46,047		48,684
Depreciation and amortization	67,115	61,540	130,288		121,642
Other regulatory charges (credits) - net	802	(9,145)	1,719		(9,952)
TOTAL	430,805	496,660	841,800		971,257
OPERATING INCOME	73,447	55,149	127,825		91,805
OTHER INCOME
Allowance for equity funds used during construction	3,995	3,532	8,927		5,906
Investment Income, Net	5,770	2,861	9,364		13,813
Miscellaneous - net	(1,020)	(521)	(1,795)		(688)
TOTAL	8,745	5,872	16,496		19,031
INTEREST EXPENSE
Interest expense	27,792	26,417	60,574		52,904
Allowance for borrowed funds used during construction	(2,136)	(1,844)	(4,851)		(3,075)
TOTAL	25,656	24,573	55,723		49,829
INCOME BEFORE INCOME TAXES	56,536	36,448	88,598		61,007
Income taxes	22,645	14,923	35,413		21,617
CONSOLIDATED NET INCOME	33,891	21,525	53,185		39,390
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	1,718	1,718	3,437		3,437
EARNINGS APPLICABLE TO COMMON STOCK	32,173	19,807	49,748		35,953
Entergy Louisiana [Member]
OPERATING REVENUES
Electric	989,732	1,064,328	1,926,163		2,109,139
Natural gas	9,302	10,270	28,016		34,651
TOTAL	999,034	1,074,598	1,954,179		2,143,790
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	152,340	176,991	354,423		396,649
Purchased power	224,699	289,560	416,097		560,759
Nuclear refueling outage expenses	12,974	11,809	25,754		22,939
Other operation and maintenance	232,957	248,277	439,021		469,078
Decommissioning	11,658	10,784	23,166		21,429
Taxes other than income taxes	44,366	40,171	86,728		84,061
Depreciation and amortization	112,452	110,758	222,043		217,626
Other regulatory charges (credits) - net	13,836	(4,820)	11,577		(5,595)
TOTAL	805,282	883,530	1,578,809		1,766,946
OPERATING INCOME	193,752	191,068	375,370		376,844
OTHER INCOME
Allowance for equity funds used during construction	4,506	4,223	11,744		9,695
Investment Income, Net	40,251	34,781	77,667		74,797
Miscellaneous - net	(1,870)	(4,588)	(5,615)		(4,788)
TOTAL	42,887	34,416	83,796		79,704
INTEREST EXPENSE
Interest expense	70,787	65,003	135,863		130,284
Allowance for borrowed funds used during construction	(2,383)	(2,365)	(6,280)		(5,493)
TOTAL	68,404	62,638	129,583		124,791
INCOME BEFORE INCOME TAXES	168,235	162,846	329,583		331,757
Income taxes	(85,090)	53,865	(35,348)		96,667
CONSOLIDATED NET INCOME	253,325	108,981	364,931		235,090
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	0	1,944	0		3,887
EARNINGS APPLICABLE TO COMMON STOCK	253,325	107,037	364,931		231,203
Entergy Mississippi [Member]
OPERATING REVENUES
Electric	248,138	344,975	511,184		705,790
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	(34)	64,208	61,346		154,819
Purchased power	74,361	95,763	129,744		187,921
Other operation and maintenance	60,381	65,114	111,654		130,186
Taxes other than income taxes	20,487	23,117	43,984		48,137
Depreciation and amortization	34,010	32,599	67,308		63,429
Other regulatory charges (credits) - net	(2,957)	6,088	(6,315)		8,373
TOTAL	186,248	286,889	407,721		592,865
OPERATING INCOME	61,890	58,086	103,463		112,925
OTHER INCOME
Allowance for equity funds used during construction	1,345	610	2,631		1,381
Investment Income, Net	240	27	361		55
Miscellaneous - net	(1,050)	(1,130)	(1,755)		(1,932)
TOTAL	535	(493)	1,237		(496)
INTEREST EXPENSE
Interest expense	15,258	14,391	30,000		28,637
Allowance for borrowed funds used during construction	(691)	(324)	(1,358)		(741)
TOTAL	14,567	14,067	28,642		27,896
INCOME BEFORE INCOME TAXES	47,858	43,526	76,058		84,533
Income taxes	15,664	17,247	26,746		33,319
CONSOLIDATED NET INCOME	32,194	26,279	49,312		51,214
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	707	707	1,414		1,414
EARNINGS APPLICABLE TO COMMON STOCK	31,487	25,572	47,898		49,800
Entergy New Orleans [Member]
OPERATING REVENUES
Electric	149,101	143,246	271,542		264,741
Natural gas	15,819	17,506	42,718		52,637
TOTAL	164,920	160,752	314,260		317,378
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	12,554	16,099	23,475		37,722
Purchased power	70,583	71,385	139,108		134,520
Other operation and maintenance	28,659	32,082	51,501		60,082
Taxes other than income taxes	10,925	11,275	22,437		23,168
Depreciation and amortization	13,908	10,080	25,672		21,600
Other regulatory charges (credits) - net	1,378	(323)	3,274		(613)
TOTAL	138,007	140,598	265,467		276,479
OPERATING INCOME	26,913	20,154	48,793		40,899
OTHER INCOME
Allowance for equity funds used during construction	143	312	456		632
Investment Income, Net	30	13	99		39
Miscellaneous - net	192	248	(53)		612
TOTAL	365	573	502		1,283
INTEREST EXPENSE
Interest expense	5,984	4,266	10,357		8,607
Allowance for borrowed funds used during construction	(49)	(144)	(175)		(294)
TOTAL	5,935	4,122	10,182		8,313
INCOME BEFORE INCOME TAXES	21,343	16,605	39,113		33,869
Income taxes	9,500	5,710	16,103		11,682
CONSOLIDATED NET INCOME	11,843	10,895	23,010		22,187
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	241	241	482		482
EARNINGS APPLICABLE TO COMMON STOCK	11,602	10,654	22,528		21,705
Entergy Texas [Member]
OPERATING REVENUES
Electric	412,922	402,921	791,226		814,132
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	71,478	50,360	163,882		124,167
Purchased power	167,071	180,843	297,483		355,048
Other operation and maintenance	54,135	66,062	107,170		122,587
Taxes other than income taxes	18,285	17,641	36,595		35,911
Depreciation and amortization	26,495	25,714	52,114		50,561
Other regulatory charges (credits) - net	17,419	18,237	34,674		37,781
TOTAL	354,883	358,857	691,918		726,055
OPERATING INCOME	58,039	44,064	99,308		88,077
OTHER INCOME
Allowance for equity funds used during construction	2,270	1,317	4,702		2,541
Investment Income, Net	268	(193)	468		(406)
Miscellaneous - net	(54)	(178)	(470)		(114)
TOTAL	2,484	946	4,700		2,021
INTEREST EXPENSE
Interest expense	21,976	21,562	43,577		42,558
Allowance for borrowed funds used during construction	(1,473)	(862)	(3,054)		(1,656)
TOTAL	20,503	20,700	40,523		40,902
INCOME BEFORE INCOME TAXES	40,020	24,310	63,485		49,196
Income taxes	15,962	9,420	24,865		17,715
CONSOLIDATED NET INCOME	24,058	14,890	38,620		31,481
System Energy [Member]
OPERATING REVENUES
Electric	151,323	163,101	289,016		319,140
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	20,394	22,943	33,822		43,416
Nuclear refueling outage expenses	4,905	5,420	9,489		11,102
Other operation and maintenance	35,766	41,083	67,926		76,789
Decommissioning	12,593	11,897	24,980		23,600
Taxes other than income taxes	6,385	6,558	12,637		13,766
Depreciation and amortization	35,384	37,247	70,091		74,307
Other regulatory charges (credits) - net	(9,124)	(7,517)	(22,415)		(17,094)
TOTAL	106,303	117,631	196,530		225,886
OPERATING INCOME	45,020	45,470	92,486		93,254
OTHER INCOME
Allowance for equity funds used during construction	1,602	2,042	4,331		3,693
Investment Income, Net	5,124	3,250	8,398		7,463
Miscellaneous - net	(164)	(217)	(256)		(438)
TOTAL	6,562	5,075	12,473		10,718
INTEREST EXPENSE
Interest expense	9,382	12,347	18,934		25,360
Allowance for borrowed funds used during construction	(401)	(540)	(1,097)		(976)
TOTAL	8,981	11,807	17,837		24,384
INCOME BEFORE INCOME TAXES	42,601	38,738	87,122		79,588
Income taxes	17,511	16,878	36,074		32,195
CONSOLIDATED NET INCOME	$ 25,090	$ 21,860	$ 51,048		$ 47,393
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $10.6 million and $6.4 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		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015
OPERATING ACTIVITIES
Consolidated net income	[1]	$ 807,832	$ 456,651
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		1,012,753	1,069,888
Deferred income taxes, investment tax credits, and non-current taxes accrued		(170,026)	180,006
Impairment of Long-Lived Assets Held-for-use		14,329	0
Changes in working capital:
Receivables		(57,673)	(100,168)
Fuel inventory		9,586	(3,748)
Accounts payable		45,412	(104,595)
Taxes accrued		7,056	(19,027)
Interest accrued		(9,543)	(18,984)
Deferred fuel costs		3,757	72,449
Other working capital accounts		(121,929)	(124,146)
Changes in provisions for estimated losses		1,533	(6,987)
Changes in other regulatory assets		109,700	124,785
Changes in other regulatory liabilities		70,505	(15,059)
Changes in pensions and other postretirement liabilities		(168,856)	(116,896)
Other Noncash Income (Expense)		(302,356)	(55,808)
Net cash flow provided by operating activities		1,252,080	1,338,361
INVESTING ACTIVITIES
Construction/capital expenditures		(1,294,498)	(1,095,926)
Allowance for equity funds used during construction		33,152	25,165
Payments to Acquire Property, Plant, and Equipment		(947,903)	0
Nuclear fuel purchases		(124,107)	(165,704)
Payments for Nuclear Fuel		(124,107)	(165,704)
NYPA value sharing payment		0	(70,790)
Payments to storm reserve escrow account		(805)	(3,689)
Decrease (increase) in other investments		57	(54,022)
Proceeds from nuclear decommissioning trust fund sales		1,232,672	948,542
Investment in nuclear decommissioning trust funds		(1,267,452)	(973,016)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		89,407	0
Proceeds from insurance		0	12,745
Changes in securitization account		13,239	6,604
Net cash flow used in investing activities		(2,266,238)	(1,370,091)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		3,856,768	865,634
Common stock and treasury stock		16,855	23,897
Retirement of long-term debt		(3,420,196)	(1,384,658)
Payments for Repurchase of Common Stock		0	(25,078)
Changes in credit borrowings and commercial paper - net		530,540	341,578
Dividends paid:
Common stock		(303,843)	(298,259)
Preferred stock		(10,552)	(9,759)
Other		(10,276)	6,719
Net cash flow provided by (used in) financing activities		659,296	(479,926)
Net decrease in cash and cash equivalents		(354,862)	(511,656)
Cash and cash equivalents at beginning of period		1,350,961	1,422,026
Cash and cash equivalents at end of period		996,099	910,370
Cash paid / (received) during the period for:
Interest - net of amount capitalized		410,744	340,993
Income taxes		84,607	90,767
Entergy Arkansas [Member]
OPERATING ACTIVITIES
Consolidated net income		53,185	39,390
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		211,630	201,426
Deferred income taxes, investment tax credits, and non-current taxes accrued		122,195	37,397
Changes in working capital:
Receivables		(42,371)	(35,452)
Fuel inventory		5,093	13,730
Accounts payable		66,118	(8,930)
Taxes accrued		(89,124)	(29,667)
Interest accrued		(1,093)	(543)
Deferred fuel costs		(40,847)	56,023
Other working capital accounts		25,021	(23,969)
Changes in provisions for estimated losses		1,142	(133)
Changes in other regulatory assets		7,048	14,173
Changes in pensions and other postretirement liabilities		(45,752)	(41,182)
Other Noncash Income (Expense)		(18,542)	(7,925)
Net cash flow provided by operating activities		253,703	214,338
INVESTING ACTIVITIES
Construction/capital expenditures		(316,569)	(268,714)
Allowance for equity funds used during construction		9,229	7,329
Payments to Acquire Property, Plant, and Equipment		(236,969)	0
Change in money pool receivable - net		(1,453)	(3,959)
Nuclear fuel purchases		(64,689)	(34,750)
Payments for Nuclear Fuel		(64,689)	(34,750)
Proceeds from sale of nuclear fuel		40,336	26,636
Proceeds from nuclear decommissioning trust fund sales		103,815	146,823
Investment in nuclear decommissioning trust funds		(112,040)	(150,453)
Changes in securitization account		1,017	(99)
Other		(103)	0
Net cash flow used in investing activities		(577,426)	(277,187)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		380,141	0
Proceeds from Contributions from Parent		200,000	0
Retirement of long-term debt		(181,604)	(6,518)
Change in money pool payable - net		(52,742)	0
Changes in credit borrowings and commercial paper - net		908	(47,968)
Dividends paid:
Preferred stock		(3,437)	(3,437)
Other		(3,566)	1,494
Net cash flow provided by (used in) financing activities		339,700	(56,429)
Net decrease in cash and cash equivalents		15,977	(119,278)
Cash and cash equivalents at beginning of period		9,135	218,505
Cash and cash equivalents at end of period		25,112	99,227
Cash paid / (received) during the period for:
Interest - net of amount capitalized		58,733	50,671
Income taxes		7,242	17,587
Entergy Louisiana [Member]
OPERATING ACTIVITIES
Consolidated net income		364,931	235,090
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		301,815	297,302
Deferred income taxes, investment tax credits, and non-current taxes accrued		(49,661)	135,120
Changes in working capital:
Receivables		(72,931)	(76,119)
Fuel inventory		(5,053)	(2,890)
Accounts payable		(22,830)	34,241
Taxes accrued		23,850	23,931
Interest accrued		(4,216)	1,985
Deferred fuel costs		4,093	(32,819)
Other working capital accounts		(26,514)	(31,192)
Changes in provisions for estimated losses		1,734	(5,165)
Changes in other regulatory assets		58,429	45,422
Changes in pensions and other postretirement liabilities		(35,869)	(24,796)
Other Noncash Income (Expense)		(97,422)	(36,288)
Net cash flow provided by operating activities		440,356	563,822
INVESTING ACTIVITIES
Construction/capital expenditures		(403,387)	(374,174)
Allowance for equity funds used during construction		11,744	9,695
Payments to Acquire Property, Plant, and Equipment		(473,956)	0
Change in money pool receivable - net		(168)	(16,941)
Nuclear fuel purchases		(38,773)	(119,798)
Payments for Nuclear Fuel		(38,773)	(119,798)
Proceeds from sale of nuclear fuel		64,498	17,070
Payments to storm reserve escrow account		0	(42)
Increase in Investments		0	(32,300)
Decrease (increase) in other investments		(544)	(5,090)
Proceeds from nuclear decommissioning trust fund sales		123,546	65,127
Investment in nuclear decommissioning trust funds		(143,091)	(80,352)
Changes in securitization account		225	9
Net cash flow used in investing activities		(859,906)	(536,796)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		1,128,580	0
Retirement of long-term debt		(559,839)	(25,368)
Changes in credit borrowings and commercial paper - net		(888)	(5,766)
Dividends paid:
Common stock		(105,500)	0
Preferred stock		0	(3,887)
Other		(3,100)	(12,389)
Net cash flow provided by (used in) financing activities		459,253	(47,410)
Net decrease in cash and cash equivalents		39,703	(20,384)
Cash and cash equivalents at beginning of period		35,102	320,516
Cash and cash equivalents at end of period		74,805	300,132
Cash paid / (received) during the period for:
Interest - net of amount capitalized		196,514	124,491
Income taxes		62,676	(4,056)
Entergy Mississippi [Member]
OPERATING ACTIVITIES
Consolidated net income		49,312	51,214
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		67,308	63,429
Deferred income taxes, investment tax credits, and non-current taxes accrued		21,934	(25,582)
Changes in working capital:
Receivables		(24,273)	14,406
Fuel inventory		(5,040)	(7,318)
Accounts payable		21,359	(11,972)
Taxes accrued		(20,417)	30,554
Interest accrued		(584)	(3,304)
Deferred fuel costs		108	58,395
Other working capital accounts		(8,266)	(6,027)
Changes in provisions for estimated losses		(188)	(203)
Changes in other regulatory assets		(1,913)	22,799
Changes in pensions and other postretirement liabilities		(10,922)	(8,971)
Other Noncash Income (Expense)		(11,355)	(3,091)
Net cash flow provided by operating activities		77,063	174,329
INVESTING ACTIVITIES
Construction/capital expenditures		(143,171)	(89,581)
Allowance for equity funds used during construction		2,631	1,381
Change in money pool receivable - net		12,416	(7,092)
Decrease (increase) in other investments		0	(5,000)
Proceeds from insurance		0	12,745
Other		(117)	(7)
Net cash flow used in investing activities		(128,241)	(87,554)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		371,940	0
Retirement of long-term debt		(332,400)	0
Dividends paid:
Common stock		(24,000)	(32,500)
Preferred stock		(1,414)	(1,414)
Other		0	(87)
Net cash flow provided by (used in) financing activities		14,126	(34,001)
Net decrease in cash and cash equivalents		(37,052)	52,774
Cash and cash equivalents at beginning of period		145,605	61,633
Cash and cash equivalents at end of period		108,553	114,407
Cash paid / (received) during the period for:
Interest - net of amount capitalized		29,157	30,637
Income taxes		(3,561)	597
Entergy New Orleans [Member]
OPERATING ACTIVITIES
Consolidated net income		23,010	22,187
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		25,672	21,600
Deferred income taxes, investment tax credits, and non-current taxes accrued		(2,665)	10,028
Changes in working capital:
Receivables		(16,285)	(840)
Fuel inventory		1,822	1,938
Accounts payable		6,362	2,313
Taxes accrued		36,982	0
Interest accrued		255	(399)
Deferred fuel costs		(13,664)	(9,557)
Other working capital accounts		(7,310)	(6,433)
Changes in provisions for estimated losses		1,804	(188)
Changes in other regulatory assets		5,799	(24,779)
Changes in pensions and other postretirement liabilities		(8,245)	(6,437)
Other Noncash Income (Expense)		(14,269)	22,428
Net cash flow provided by operating activities		39,268	31,861
INVESTING ACTIVITIES
Construction/capital expenditures		(37,345)	(32,659)
Allowance for equity funds used during construction		456	632
Payments to Acquire Property, Plant, and Equipment		(236,978)	0
Proceeds from Divestiture of Businesses and Interests in Affiliates		(38)	0
Change in money pool receivable - net		12,787	(1,504)
Payments to storm reserve escrow account		(206)	(3,553)
Receipts from storm reserve escrow account		3	3
Changes in securitization account		3,285	0
Net cash flow used in investing activities		(258,036)	(37,081)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		190,672	0
Proceeds from Contributions from Parent		47,750	0
Retirement of long-term debt		(77,094)	0
Dividends paid:
Common stock		(7,000)	(7,250)
Preferred stock		(482)	(482)
Other		664	(82)
Net cash flow provided by (used in) financing activities		154,510	(7,814)
Net decrease in cash and cash equivalents		(64,258)	(13,034)
Cash and cash equivalents at beginning of period		88,876	42,389
Cash and cash equivalents at end of period		24,618	29,355
Cash paid / (received) during the period for:
Interest - net of amount capitalized		9,435	8,501
Income taxes		2,500	40
Entergy Texas [Member]
OPERATING ACTIVITIES
Consolidated net income		38,620	31,481
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		52,114	50,561
Deferred income taxes, investment tax credits, and non-current taxes accrued		(40,175)	(63,659)
Changes in working capital:
Receivables		(37,832)	471
Fuel inventory		14,129	(4,287)
Accounts payable		17,883	7,553
Taxes accrued		51,640	69,446
Interest accrued		(2,719)	447
Deferred fuel costs		54,066	252
Other working capital accounts		2,774	7,209
Changes in provisions for estimated losses		(2,126)	(1,093)
Changes in other regulatory assets		43,378	53,242
Changes in pensions and other postretirement liabilities		(12,850)	(9,860)
Other Noncash Income (Expense)		(6,727)	(9,921)
Net cash flow provided by operating activities		172,175	131,842
INVESTING ACTIVITIES
Construction/capital expenditures		(185,945)	(133,344)
Allowance for equity funds used during construction		4,761	2,571
Change in money pool receivable - net		(7,011)	(1,952)
Changes in securitization account		8,712	6,694
Other		0	(12,000)
Net cash flow used in investing activities		(179,483)	(138,031)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		123,605	247,005
Retirement of long-term debt		(36,659)	(235,260)
Change in money pool payable - net		(22,068)	0
Dividends paid:
Other		(3,815)	(1,296)
Net cash flow provided by (used in) financing activities		61,063	10,449
Net decrease in cash and cash equivalents		53,755	4,260
Cash and cash equivalents at beginning of period		2,182	30,441
Cash and cash equivalents at end of period		55,937	34,701
Cash paid / (received) during the period for:
Interest - net of amount capitalized		45,056	40,252
Income taxes		3,443	3,162
System Energy [Member]
OPERATING ACTIVITIES
Consolidated net income		51,048	47,393
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		123,424	136,091
Deferred income taxes, investment tax credits, and non-current taxes accrued		83,733	6,699
Changes in working capital:
Receivables		3,731	2,286
Accounts payable		(3,200)	(746)
Taxes accrued		(60,954)	(9,355)
Interest accrued		(145)	(17,070)
Other working capital accounts		(28,319)	3,148
Changes in other regulatory assets		(9,844)	(7)
Changes in pensions and other postretirement liabilities		(9,071)	(6,620)
Other Noncash Income (Expense)		(13,111)	(12,753)
Net cash flow provided by operating activities		137,292	149,066
INVESTING ACTIVITIES
Construction/capital expenditures		(57,429)	(27,608)
Allowance for equity funds used during construction		4,331	3,693
Change in money pool receivable - net		22,208	(5,147)
Nuclear fuel purchases		(130,275)	(26,831)
Payments for Nuclear Fuel		(130,275)	(26,831)
Proceeds from sale of nuclear fuel		11,467	21,263
Proceeds from nuclear decommissioning trust fund sales		289,414	161,977
Investment in nuclear decommissioning trust funds		(307,465)	(177,214)
Net cash flow used in investing activities		(167,749)	(49,867)
Proceeds from the issuance of:
Retirement of long-term debt		(22,001)	(106,405)
Changes in credit borrowings and commercial paper - net		99,617	17,102
Dividends paid:
Common stock		(139,000)	(122,000)
Other		(26)	(28)
Net cash flow provided by (used in) financing activities		(61,410)	(211,331)
Net decrease in cash and cash equivalents		(91,867)	(112,132)
Cash and cash equivalents at beginning of period		230,661	223,179
Cash and cash equivalents at end of period		138,794	111,047
Cash paid / (received) during the period for:
Interest - net of amount capitalized		18,494	37,929
Income taxes		$ 3,402	$ 25,304
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $10.6 million and $6.4 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	Jun. 30, 2016	Dec. 31, 2015
Cash and cash equivalents:
Cash	$ 103,282	$ 63,497
Temporary cash investments	892,817	1,287,464
Total cash and cash equivalents	996,099	1,350,961
Accounts receivable:
Customer	542,598	608,491
Allowance for doubtful accounts	(42,938)	(39,895)
Other	237,480	178,364
Accrued unbilled revenues	432,830	321,940
Total accounts receivable	1,169,970	1,068,900
Deferred fuel costs	31,895	0
Fuel inventory - at average cost	208,224	217,810
Materials and supplies - at average cost	903,973	873,357
Deferred nuclear refueling outage costs	248,932	211,512
Prepayments and other	292,835	344,872
TOTAL	3,851,928	4,067,412
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	4,845	4,341
Decommissioning trust funds	5,555,651	5,349,953
Non-utility property - at cost (less accumulated depreciation)	225,996	219,999
Other	469,791	468,704
TOTAL	6,256,283	6,042,997
PROPERTY, PLANT, AND EQUIPMENT
Electric	46,947,112	44,467,159
Property under capital lease	610,225	952,465
Natural gas	400,423	392,032
Construction work in progress	1,258,370	1,456,735
Nuclear fuel	1,246,430	1,345,422
TOTAL PROPERTY, PLANT, AND EQUIPMENT	50,462,560	48,613,813
Less - accumulated depreciation and amortization	21,392,881	20,789,452
PROPERTY, PLANT, AND EQUIPMENT - NET	29,069,679	27,824,361
Regulatory assets:
Regulatory asset for income taxes - net	769,535	775,528
Other regulatory assets	4,603,489	4,704,796
Deferred fuel costs	239,001	238,902
Goodwill	377,172	377,172
Accumulated deferred income taxes	122,389	54,903
Other	587,566	561,610
TOTAL	6,699,152	6,712,911
TOTAL ASSETS	45,877,042	44,647,681
CURRENT LIABILITIES
Currently maturing long-term debt	671,732	214,374
Notes payable and commercial paper	1,024,888	494,348
Accounts payable	967,080	1,071,798
Customer deposits	424,977	419,407
Taxes Payable, Current	217,133	210,077
Interest accrued	185,021	194,565
Deferred fuel costs	271,736	235,986
Obligations under capital leases	2,815	2,709
Pension and other postretirement liabilities	62,789	62,513
Other	193,672	184,181
TOTAL	4,021,843	3,089,958
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	8,183,048	8,306,865
Accumulated deferred investment tax credits	228,917	234,300
Obligations under capital leases	25,567	27,001
Other regulatory liabilities	1,485,402	1,414,898
Decommissioning and asset retirement cost liabilities	4,868,788	4,790,187
Accumulated provisions	462,214	460,727
Pension and other postretirement liabilities	3,018,226	3,187,357
Long-term debt	13,112,072	13,111,556
Other	394,993	449,856
TOTAL	31,779,227	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	5,392,546	5,403,758
Retained earnings	9,887,350	9,393,913
Accumulated other comprehensive income (loss)	(9,155)	8,951
Less - treasury stock, at cost	5,515,502	5,552,379
TOTAL	9,757,787	9,256,791
TOTAL	9,757,787	9,256,791
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	45,877,042	44,647,681
Entergy Arkansas [Member]
Cash and cash equivalents:
Cash	13,780	9,066
Temporary cash investments	11,332	69
Total cash and cash equivalents	25,112	9,135
Securitization recovery trust account	3,187	4,204
Accounts receivable:
Customer	107,896	108,636
Allowance for doubtful accounts	(34,401)	(34,226)
Associated companies	33,069	32,987
Other	82,046	84,216
Accrued unbilled revenues	121,151	73,583
Total accounts receivable	309,761	265,196
Deferred fuel costs	31,895	0
Fuel inventory - at average cost	57,596	62,689
Materials and supplies - at average cost	178,563	169,919
Deferred nuclear refueling outage costs	38,372	67,834
Prepaid Taxes	119,415	30,291
Prepayments and other	25,692	15,145
TOTAL	789,593	624,413
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	802,763	771,313
Other	7,915	12,895
TOTAL	810,678	784,208
PROPERTY, PLANT, AND EQUIPMENT
Electric	10,171,128	9,536,802
Property under capital lease	779	844
Construction work in progress	309,915	388,075
Nuclear fuel	256,222	286,341
TOTAL PROPERTY, PLANT, AND EQUIPMENT	10,738,044	10,212,062
Less - accumulated depreciation and amortization	4,517,372	4,349,809
PROPERTY, PLANT, AND EQUIPMENT - NET	6,220,672	5,862,253
Regulatory assets:
Regulatory asset for income taxes - net	62,273	61,438
Other regulatory assets	1,325,890	1,333,773
Deferred fuel costs	66,799	66,700
Other	19,892	14,989
TOTAL	1,474,854	1,476,900
TOTAL ASSETS	9,295,797	8,747,774
CURRENT LIABILITIES
Currently maturing long-term debt	55,000	55,000
Short-term borrowings	12,599	11,690
Associated companies accounts payable	137,691	110,464
Other	130,621	177,758
Customer deposits	119,586	118,340
Interest accrued	18,790	19,883
Deferred fuel costs	0	8,853
Other	51,610	45,219
TOTAL	525,897	547,207
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	2,100,985	1,982,812
Accumulated deferred investment tax credits	35,906	36,506
Other regulatory liabilities	266,938	242,913
Decommissioning and asset retirement cost liabilities	898,750	872,346
Accumulated provisions	6,694	5,552
Pension and other postretirement liabilities	413,401	459,153
Long-term debt	2,775,658	2,574,839
Other	13,812	18,438
TOTAL	6,512,144	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	1,352,443	1,302,695
TOTAL	2,141,406	1,891,658
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	9,295,797	8,747,774
Entergy Louisiana [Member]
Cash and cash equivalents:
Cash	24,659	348
Temporary cash investments	50,146	34,754
Total cash and cash equivalents	74,805	35,102
Accounts receivable:
Customer	167,646	179,051
Allowance for doubtful accounts	(6,633)	(4,209)
Associated companies	131,488	94,418
Other	112,044	56,793
Accrued unbilled revenues	180,343	143,079
Total accounts receivable	584,888	469,132
Fuel inventory - at average cost	53,098	48,045
Materials and supplies - at average cost	305,376	282,688
Deferred nuclear refueling outage costs	41,548	66,984
Hedging Assets, Current	12,817	0
Prepayments and other	45,300	28,294
TOTAL	1,117,832	930,245
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	1,390,587	1,390,587
Decommissioning trust funds	1,094,817	1,042,293
Non-utility property - at cost (less accumulated depreciation)	212,741	206,293
Storm Reserve Escrow Account	290,966	290,422
Other	28,920	14,776
TOTAL	3,018,031	2,944,371
PROPERTY, PLANT, AND EQUIPMENT
Electric	18,891,958	17,629,077
Property under capital lease	0	341,514
Natural gas	165,193	159,252
Construction work in progress	382,197	420,874
Nuclear fuel	289,234	386,524
TOTAL PROPERTY, PLANT, AND EQUIPMENT	19,728,582	18,937,241
Less - accumulated depreciation and amortization	8,594,494	8,302,774
PROPERTY, PLANT, AND EQUIPMENT - NET	11,134,088	10,634,467
Regulatory assets:
Regulatory asset for income taxes - net	474,456	478,243
Other regulatory assets	1,163,232	1,217,874
Deferred fuel costs	168,122	168,122
Other	20,081	14,125
TOTAL	1,825,891	1,878,364
TOTAL ASSETS	17,095,842	16,387,447
CURRENT LIABILITIES
Currently maturing long-term debt	61,004	29,372
Short-term borrowings	59,469	60,356
Associated companies accounts payable	102,443	165,419
Other	268,030	276,280
Customer deposits	148,760	146,555
Taxes Payable, Current	148,992	125,142
Interest accrued	70,164	74,380
Deferred fuel costs	69,327	65,234
Other	88,794	79,982
TOTAL	1,016,983	1,022,720
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	2,447,814	2,506,956
Accumulated deferred investment tax credits	129,251	131,760
Regulatory liability for income taxes - net	0	2,473
Other regulatory liabilities	848,739	818,623
Decommissioning and asset retirement cost liabilities	1,054,914	1,027,862
Accumulated provisions	312,016	310,282
Pension and other postretirement liabilities	797,246	833,185
Long-term debt	5,349,214	4,806,790
Long-term payables of associated companies	403	1,073
Other	143,027	188,411
TOTAL	11,082,624	10,627,415
Common Shareholders' Equity:
Accumulated other comprehensive income (loss)	(56,905)	(56,412)
Members' Equity	5,053,140	4,793,724
TOTAL	4,996,235	4,737,312
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	17,095,842	16,387,447
Entergy Mississippi [Member]
Cash and cash equivalents:
Cash	3,276	1,426
Temporary cash investments	105,277	144,179
Total cash and cash equivalents	108,553	145,605
Accounts receivable:
Customer	39,890	56,685
Allowance for doubtful accounts	(505)	(718)
Associated companies	47,985	34,964
Other	7,436	8,276
Accrued unbilled revenues	63,542	47,284
Total accounts receivable	158,348	146,491
Fuel inventory - at average cost	56,313	51,273
Materials and supplies - at average cost	40,180	39,491
Prepayments and other	14,015	5,184
TOTAL	377,409	388,044
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,617	4,625
Escrow accounts	31,786	41,726
TOTAL	36,403	46,351
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,188,885	4,083,933
Property under capital lease	2,281	2,942
Construction work in progress	103,644	114,067
TOTAL PROPERTY, PLANT, AND EQUIPMENT	4,294,810	4,200,942
Less - accumulated depreciation and amortization	1,559,956	1,534,522
PROPERTY, PLANT, AND EQUIPMENT - NET	2,734,854	2,666,420
Regulatory assets:
Regulatory asset for income taxes - net	40,744	45,790
Other regulatory assets	338,040	328,681
Other	5,143	2,121
TOTAL	383,927	376,592
TOTAL ASSETS	3,532,593	3,477,407
CURRENT LIABILITIES
Currently maturing long-term debt	0	125,000
Associated companies accounts payable	38,899	38,496
Other	63,384	51,502
Customer deposits	83,180	81,583
Taxes Payable, Current	23,044	43,461
Interest accrued	20,247	20,831
Deferred fuel costs	107,862	107,754
Other	12,471	22,754
TOTAL	349,087	491,381
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	825,814	810,635
Accumulated deferred investment tax credits	4,565	4,645
Decommissioning and asset retirement cost liabilities	8,484	8,252
Accumulated provisions	47,874	48,062
Pension and other postretirement liabilities	109,292	120,217
Long-term debt	1,091,938	920,085
Other	9,210	11,699
TOTAL	2,097,177	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	837,312	813,414
TOTAL	1,035,948	1,012,050
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	3,532,593	3,477,407
Entergy New Orleans [Member]
Cash and cash equivalents:
Cash	1,206	1,068
Temporary cash investments	23,412	87,808
Total cash and cash equivalents	24,618	88,876
Securitization recovery trust account	1,335	4,620
Accounts receivable:
Customer	43,032	34,627
Allowance for doubtful accounts	(843)	(268)
Associated companies	13,120	23,248
Other	6,027	3,753
Accrued unbilled revenues	21,321	17,799
Total accounts receivable	82,657	79,159
Fuel inventory - at average cost	90	1,912
Materials and supplies - at average cost	15,273	13,244
Prepayments and other	15,974	10,263
TOTAL	139,947	198,074
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	1,016	1,016
Storm Reserve Escrow Account	81,206	81,002
Other	7,160	3
TOTAL	89,382	82,021
PROPERTY, PLANT, AND EQUIPMENT
Electric	1,236,377	1,051,239
Natural gas	235,229	232,780
Construction work in progress	26,119	29,027
TOTAL PROPERTY, PLANT, AND EQUIPMENT	1,497,725	1,313,046
Less - accumulated depreciation and amortization	594,956	648,081
PROPERTY, PLANT, AND EQUIPMENT - NET	902,769	664,965
Regulatory assets:
Other regulatory assets	259,523	265,322
Deferred fuel costs	4,080	4,080
Other	1,458	682
TOTAL	265,061	270,084
TOTAL ASSETS	1,397,159	1,215,144
CURRENT LIABILITIES
Current payable due Entergy Louisiana	4,973	4,973
Associated companies accounts payable	37,805	37,467
Other	26,164	21,471
Customer deposits	28,471	28,392
Taxes Payable, Current	36,982	0
Interest accrued	5,164	4,909
Deferred fuel costs	15,357	29,021
Other	11,647	6,216
TOTAL	166,563	132,449
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	190,793	214,061
Accumulated deferred investment tax credits	687	753
Regulatory liability for income taxes - net	10,591	13,199
Decommissioning and asset retirement cost liabilities	2,779	2,687
Accumulated provisions	85,991	84,187
Pension and other postretirement liabilities	35,364	43,609
Long-term debt	433,595	317,380
Gas system rebuild insurance proceeds	7,105	12,788
Long-term payable due to Entergy Louisiana	20,527	20,527
Other	10,074	3,692
TOTAL	797,506	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	208,022	192,494
TOTAL	413,310	350,032
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	1,397,159	1,215,144
Entergy Texas [Member]
Cash and cash equivalents:
Cash	1,300	2,153
Temporary cash investments	54,637	29
Total cash and cash equivalents	55,937	2,182
Securitization recovery trust account	29,449	38,161
Accounts receivable:
Customer	58,963	61,870
Allowance for doubtful accounts	(556)	(474)
Associated companies	80,944	42,279
Other	13,944	11,054
Accrued unbilled revenues	46,472	40,195
Total accounts receivable	199,767	154,924
Fuel inventory - at average cost	32,813	46,942
Materials and supplies - at average cost	36,730	34,994
Prepayments and other	17,235	17,975
TOTAL	371,931	295,178
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	605	620
Non-utility property - at cost (less accumulated depreciation)	376	376
Other	20,667	20,186
TOTAL	21,648	21,182
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,103,274	3,923,100
Construction work in progress	158,630	210,964
TOTAL PROPERTY, PLANT, AND EQUIPMENT	4,261,904	4,134,064
Less - accumulated depreciation and amortization	1,494,506	1,477,529
PROPERTY, PLANT, AND EQUIPMENT - NET	2,767,398	2,656,535
Regulatory assets:
Regulatory asset for income taxes - net	107,715	107,499
Other regulatory assets	769,268	812,862
Other	6,741	5,326
TOTAL	883,724	925,687
TOTAL ASSETS	4,044,701	3,898,582
CURRENT LIABILITIES
Associated companies accounts payable	96,270	106,065
Other	71,430	87,421
Customer deposits	44,981	44,537
Taxes Payable, Current	56,973	5,333
Interest accrued	26,487	29,206
Deferred fuel costs	79,190	25,124
Other	13,678	10,363
TOTAL	389,009	308,049
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	964,794	1,006,834
Accumulated deferred investment tax credits	13,384	13,835
Other regulatory liabilities	6,269	6,396
Decommissioning and asset retirement cost liabilities	6,294	6,124
Accumulated provisions	7,193	9,319
Pension and other postretirement liabilities	64,678	77,517
Long-term debt	1,539,889	1,451,967
Other	53,115	57,085
TOTAL	2,655,616	2,629,077
Common Shareholders' Equity:
Common stock	49,452	49,452
Paid-in capital	481,994	481,994
Retained earnings	468,630	430,010
TOTAL	1,000,076	961,456
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	4,044,701	3,898,582
System Energy [Member]
Cash and cash equivalents:
Cash	792	8,681
Temporary cash investments	138,002	221,980
Total cash and cash equivalents	138,794	230,661
Accounts receivable:
Associated companies	68,252	93,724
Other	4,107	4,574
Total accounts receivable	72,359	98,298
Materials and supplies - at average cost	81,551	87,366
Deferred nuclear refueling outage costs	34,887	5,605
Prepaid Taxes	70,281	9,327
Prepayments and other	6,818	1,955
TOTAL	404,690	433,212
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	741,112	701,460
TOTAL	741,112	701,460
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,327,329	4,253,949
Property under capital lease	575,027	575,027
Construction work in progress	56,277	92,546
Nuclear fuel	263,116	183,706
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,221,749	5,105,228
Less - accumulated depreciation and amortization	3,013,134	2,961,842
PROPERTY, PLANT, AND EQUIPMENT - NET	2,208,615	2,143,386
Regulatory assets:
Regulatory asset for income taxes - net	94,937	98,230
Other regulatory assets	360,967	347,830
Other	4,864	4,757
TOTAL	460,768	450,817
TOTAL ASSETS	3,815,185	3,728,875
CURRENT LIABILITIES
Currently maturing long-term debt	50,002	2
Short-term borrowings	99,617	0
Associated companies accounts payable	6,939	7,391
Other	22,383	34,010
Interest accrued	14,038	14,183
Other	1,937	1,926
TOTAL	194,916	57,512
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	1,097,454	1,019,075
Accumulated deferred investment tax credits	43,841	45,451
Other regulatory liabilities	353,331	337,424
Decommissioning and asset retirement cost liabilities	828,385	803,405
Pension and other postretirement liabilities	103,193	112,264
Long-term debt	500,924	572,665
Other	14	0
TOTAL	2,927,142	2,890,284
Common Shareholders' Equity:
Common stock	679,350	719,350
Retained earnings	13,777	61,729
TOTAL	693,127	781,079
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$ 3,815,185	$ 3,728,875

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Securitization property	$ 665,535	$ 714,044
Securitization bonds	$ 716,201	$ 774,696
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	500,000,000	500,000,000
Common stock, shares issued	254,752,788	254,752,788
Treasury stock, shares	75,856,619	76,363,763
Entergy Arkansas [Member]
Securitization property	$ 48,788	$ 54,450
Securitization bonds	$ 54,807	$ 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	$ 104,520	$ 114,701
Securitization bonds	$ 110,717	$ 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	$ 87,622	$ 91,599
Securitization bonds	$ 90,002	$ 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	$ 424,606	$ 453,317
Securitization bonds	$ 460,675	$ 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	$ 4,346,987	$ 110,000	$ 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	456,651	[1]	9,759	[1]	0	0	0	446,892	[1]	0	39,390	0	0	39,390	235,090	0	235,090	0	51,214	0	0	51,214	22,187	0	0	22,187	31,481	0	0	31,481	47,393	0	47,393
Net income attributable to Entergy Louisiana																							(631)	0	0	(631)
Other comprehensive income (loss)	(4,509)		0		0	0	0	0		(4,509)					792	0	0	792
Payments for Repurchase of Common Stock	(25,078)		0		0	(25,078)	0	0		0
Common stock issuances related to stock plans	31,425		0		0	44,445	(13,020)	0		0
Common stock dividends declared	(298,259)		0		0	0	0	(298,259)		0									(32,500)	0	0	(32,500)	(7,250)	0	0	(7,250)					(122,000)	0	(122,000)
Proceeds from Contributions from Parent											0												0
Preferred dividend requirements of subsidiaries	(9,759)	[1]	(9,759)	[1]	0	0	0	0		0	(3,437)	0	0	(3,437)	(3,887)	0	(3,887)	0	(1,414)	0	0	(1,414)	(482)	0	0	(482)
Other															(15)	0	(15)	0
Ending Balance at Jun. 30, 2015	10,252,196		94,000		2,548	(5,478,159)	5,362,333	10,318,290		(46,816)	1,860,190	470	588,471	1,271,249	4,578,967	110,000	4,547,398	(78,431)	979,470	199,326	(690)	780,834	241,849	33,744	36,294	171,811	923,312	49,452	481,994	391,866	795,904	789,350	6,554
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	807,832	[1]	10,552	[1]	0	0	0	797,280	[1]	0	53,185	0	0	53,185	364,931	0	364,931	0	49,312	0	0	49,312	23,010	0	0	23,010	38,620	0	0	38,620	51,048	0	51,048
Other comprehensive income (loss)	(18,106)		0		0	0	0	0		(18,106)					(493)	0	0	(493)
Payments for Repurchase of Common Stock	0
Common stock issuances related to stock plans	25,665		0		0	36,877	(11,212)	0		0
Common stock dividends declared	(303,843)		0		0	0	0	(303,843)		0					(105,500)	0	(105,500)	0	(24,000)	0	0	(24,000)	(7,000)	0	0	(7,000)					(139,000)	(40,000)	(99,000)
Proceeds from Contributions from Parent											200,000	0	200,000	0									47,750	0	47,750	0
Preferred dividend requirements of subsidiaries	(10,552)	[1]	(10,552)	[1]	0	0	0	0		0	(3,437)	0	0	(3,437)					(1,414)	0	0	(1,414)	(482)	0	0	(482)
Other															(15)	0	(15)	0
Ending Balance at Jun. 30, 2016	$ 9,757,787		$ 0		$ 2,548	$ (5,515,502)	$ 5,392,546	$ 9,887,350		$ (9,155)	$ 2,141,406	$ 470	$ 788,493	$ 1,352,443	$ 4,996,235	$ 0	$ 5,053,140	$ (56,905)	$ 1,035,948	$ 199,326	$ (690)	$ 837,312	$ 413,310	$ 33,744	$ 171,544	$ 208,022	$ 1,000,076	$ 49,452	$ 481,994	$ 468,630	$ 693,127	$ 679,350	$ 13,777
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $10.6 million and $6.4 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	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Statement of Stockholders' Equity [Abstract]
Preferred dividends on subsidiaries' preferred stock	$ 10.6	$ 6.4

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016		Jun. 30, 2015
Net income	$ 572,590	$ 153,722	$ 807,832	[1]	$ 456,651	[1]
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss)	(64,041)	38,696	(73,547)		9,366
Pension and other postretirement liabilities	5,043	7,438	12,605		15,886
Net unrealized investment gains	20,955	(33,880)	44,024		(29,877)
Foreign currency translation	(904)	667	(1,188)		116
Other comprehensive income (loss)	(38,947)	12,921	(18,106)		(4,509)
Total comprehensive income	533,643	166,643	789,726		452,142
Preferred dividend requirements of subsidiaries	5,276	4,879	10,552	[1]	9,759	[1]
Comprehensive Income Attributable to Entergy Corporation	528,367	161,764	779,174		442,383
Entergy Louisiana [Member]
Net income	253,325	108,981	364,931		235,090
Other comprehensive income (loss)
Pension and other postretirement liabilities	(230)	412	(493)		792
Other comprehensive income (loss)	(230)	412	(493)		792
Total comprehensive income	$ 253,095	$ 109,393	$ 364,438		235,882
Preferred dividend requirements of subsidiaries					$ 3,887
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $10.6 million and $6.4 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		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Cash flow hedges net unrealized gain (loss), tax expense (benefit)	$ (34,576)	$ 20,706	$ (39,777)	$ 4,808
Pension and other postretirement liabilities, tax expense	2,779	4,165	3,037	7,340
Net unrealized investment gains, tax expense	19,515	(30,292)	37,873	(26,626)
Foreign currency translation, tax expense	(487)	359	(640)	62
Entergy Louisiana [Member]
Pension and other postretirement liabilities, tax expense	$ (144)	$ 257	$ (259)	$ 545

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2016
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident and subsequent NRC reviews. As discussed in the Form 10-K, in March 2015 the NRC issued a letter notifying Entergy of its decision to move ANO into the “multiple/repetitive degraded cornerstone column” (Column 4) of the NRC’s Reactor Oversight Process Action Matrix. Placement into Column 4 requires significant additional NRC inspection activities at the ANO site, including a review of the site’s root cause evaluation associated with the flood barrier and stator issues, an assessment of the effectiveness of the site’s corrective action program, an additional design basis inspection, a safety culture assessment, and possibly other inspection activities consistent with the NRC’s Inspection Procedure. Entergy Arkansas incurred incremental expenses of approximately $53 million in 2015 to prepare for the NRC inspection that began in early 2016. Excluding remediation and response costs that may result from the additional NRC inspection activities, Entergy Arkansas expects to incur incremental expenses of approximately $50 million in 2016, of which $30.6 million was incurred as of June 30, 2016, in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. A lesser amount of incremental expenses is expected to be ongoing annually after 2016, until ANO transitions out of Column 4. The NRC completed the supplemental inspection required for ANO’s Column 4 designation in February 2016, and published its inspection report in June 2016. In its inspection report, the NRC concluded that the ANO site is being operated safely and that Entergy understands the depth and breadth of performance concerns associated with ANO’s performance decline. Also in June 2016, the NRC issued a confirmatory action letter to confirm the actions Entergy Arkansas has taken and will continue to take to improve performance at ANO. The NRC will verify the completion of those actions through quarterly follow-up inspections, the results of which will determine when ANO should transition out of Column 4. Pilgrim NRC Oversight and Planned Shutdown In September 2015 the NRC placed Pilgrim in its “multiple/repetitive degraded cornerstone column” (Column 4) of its Reactor Oversight Process Action Matrix due to its finding of continuing weaknesses in Pilgrim’s corrective action program that contributed to repeated unscheduled shutdowns and equipment failures. The preliminary estimate of direct costs of Pilgrim’s response to a planned NRC enhanced inspection ranges from $45 million to $60 million in operation and maintenance expense, including approximately $30 million in 2016, of which $12 million was incurred as of June 30, 2016. The estimate does not include potential capital investment or other costs to address issues that may arise in the inspection. Entergy determined in April 2016 that it intends to refuel Pilgrim in 2017 and then cease operations May 31, 2019. In October 2015, Entergy previously announced its intention to cease operations at Pilgrim because of poor market conditions, reduced revenues, and increased operational costs. Pilgrim currently has approximately 677 MW of Capacity Supply Obligations in ISO New England through May 2019. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the current Presidential administration’s defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Management cannot predict the potential timing or magnitude of future spent fuel fee revisions that may occur. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2016 related to Entergy’s nuclear owner licensee subsidiaries litigation with the DOE. In December 2015 the U.S. Court of Federal Claims issued a judgment in the amount of $81 million in favor of Entergy Nuclear Indian Point 3 and Entergy Nuclear FitzPatrick in the first round Indian Point 3/FitzPatrick damages case, and Entergy received the payment from the U.S. Treasury in June 2016. The effect of recording the Indian Point 3 proceeds was a reduction to plant, other operation and maintenance expense, and depreciation expense. The Indian Point 3 damages award included $45 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $45 million, Entergy recorded $8 million as a reduction to previously-recorded depreciation expense. Entergy reduced its Indian Point 3 plant asset balance by the remaining $37 million . The effect of recording the FitzPatrick proceeds was a reduction to plant and other operation and maintenance expense. The FitzPatrick damages awarded included $32 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $32 million, Entergy recorded an $11 million reduction to bring its remaining FitzPatrick plant asset balance to zero . The remaining $21 million was recorded as a reduction to other operation and maintenance expense because FitzPatrick’s plant asset balance is fully impaired. In April 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $42 million in favor of Entergy Louisiana and against the DOE in the first round River Bend damages case, reserving the issue of cask loading costs pending resolution of the appeal on the same issues in the Entergy Arkansas and System Energy cases. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Louisiana requested payment from the U.S. Treasury of the $42 million in June 2016 and recorded a receivable as of June 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The River Bend damages award included $17 million related to costs previously capitalized, $23 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $17 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its River Bend plant asset balance by the remaining $14 million . In May 2016, Entergy Nuclear Vermont Yankee and the DOE entered into a stipulation agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $19 million in favor of Entergy Nuclear Vermont Yankee and against the DOE in the second round Vermont Yankee damages case. Entergy received payment from the U.S. Treasury in June 2016. The effect of recording the proceeds was a reduction to other operation and maintenance expense and depreciation expense. The damages awarded included $15 million related to costs previously capitalized and $4 million related to costs previously recorded as other operation and maintenance expense. Of the $15 million, Entergy recorded $2 million as a reduction to previously-recorded depreciation expense. The remaining $13 million would have been recorded as a reduction to Vermont Yankee’s plant asset balance, but was recorded as a reduction to other operation and maintenance expense because Vermont Yankee’s plant asset balance is fully impaired. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Conventional Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Louisiana, 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 $30.6 million was incurred as of June 30, 2016, in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. A lesser amount of incremental expenses is expected to be ongoing annually after 2016, until ANO transitions out of Column 4. The NRC completed the supplemental inspection required for ANO’s Column 4 designation in February 2016, and published its inspection report in June 2016. In its inspection report, the NRC concluded that the ANO site is being operated safely and that Entergy understands the depth and breadth of performance concerns associated with ANO’s performance decline. Also in June 2016, the NRC issued a confirmatory action letter to confirm the actions Entergy Arkansas has taken and will continue to take to improve performance at ANO. The NRC will verify the completion of those actions through quarterly follow-up inspections, the results of which will determine when ANO should transition out of Column 4. Pilgrim NRC Oversight and Planned Shutdown In September 2015 the NRC placed Pilgrim in its “multiple/repetitive degraded cornerstone column” (Column 4) of its Reactor Oversight Process Action Matrix due to its finding of continuing weaknesses in Pilgrim’s corrective action program that contributed to repeated unscheduled shutdowns and equipment failures. The preliminary estimate of direct costs of Pilgrim’s response to a planned NRC enhanced inspection ranges from $45 million to $60 million in operation and maintenance expense, including approximately $30 million in 2016, of which $12 million was incurred as of June 30, 2016. The estimate does not include potential capital investment or other costs to address issues that may arise in the inspection. Entergy determined in April 2016 that it intends to refuel Pilgrim in 2017 and then cease operations May 31, 2019. In October 2015, Entergy previously announced its intention to cease operations at Pilgrim because of poor market conditions, reduced revenues, and increased operational costs. Pilgrim currently has approximately 677 MW of Capacity Supply Obligations in ISO New England through May 2019. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the current Presidential administration’s defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Management cannot predict the potential timing or magnitude of future spent fuel fee revisions that may occur. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2016 related to Entergy’s nuclear owner licensee subsidiaries litigation with the DOE. In December 2015 the U.S. Court of Federal Claims issued a judgment in the amount of $81 million in favor of Entergy Nuclear Indian Point 3 and Entergy Nuclear FitzPatrick in the first round Indian Point 3/FitzPatrick damages case, and Entergy received the payment from the U.S. Treasury in June 2016. The effect of recording the Indian Point 3 proceeds was a reduction to plant, other operation and maintenance expense, and depreciation expense. The Indian Point 3 damages award included $45 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $45 million, Entergy recorded $8 million as a reduction to previously-recorded depreciation expense. Entergy reduced its Indian Point 3 plant asset balance by the remaining $37 million . The effect of recording the FitzPatrick proceeds was a reduction to plant and other operation and maintenance expense. The FitzPatrick damages awarded included $32 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $32 million, Entergy recorded an $11 million reduction to bring its remaining FitzPatrick plant asset balance to zero . The remaining $21 million was recorded as a reduction to other operation and maintenance expense because FitzPatrick’s plant asset balance is fully impaired. In April 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $42 million in favor of Entergy Louisiana and against the DOE in the first round River Bend damages case, reserving the issue of cask loading costs pending resolution of the appeal on the same issues in the Entergy Arkansas and System Energy cases. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Louisiana requested payment from the U.S. Treasury of the $42 million in June 2016 and recorded a receivable as of June 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The River Bend damages award included $17 million related to costs previously capitalized, $23 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $17 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its River Bend plant asset balance by the remaining $14 million . In May 2016, Entergy Nuclear Vermont Yankee and the DOE entered into a stipulation agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $19 million in favor of Entergy Nuclear Vermont Yankee and against the DOE in the second round Vermont Yankee damages case. Entergy received payment from the U.S. Treasury in June 2016. The effect of recording the proceeds was a reduction to other operation and maintenance expense and depreciation expense. The damages awarded included $15 million related to costs previously capitalized and $4 million related to costs previously recorded as other operation and maintenance expense. Of the $15 million, Entergy recorded $2 million as a reduction to previously-recorded depreciation expense. The remaining $13 million would have been recorded as a reduction to Vermont Yankee’s plant asset balance, but was recorded as a reduction to other operation and maintenance expense because Vermont Yankee’s plant asset balance is fully impaired. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Conventional Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Louisiana, 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 $30.6 million was incurred as of June 30, 2016, in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. A lesser amount of incremental expenses is expected to be ongoing annually after 2016, until ANO transitions out of Column 4. The NRC completed the supplemental inspection required for ANO’s Column 4 designation in February 2016, and published its inspection report in June 2016. In its inspection report, the NRC concluded that the ANO site is being operated safely and that Entergy understands the depth and breadth of performance concerns associated with ANO’s performance decline. Also in June 2016, the NRC issued a confirmatory action letter to confirm the actions Entergy Arkansas has taken and will continue to take to improve performance at ANO. The NRC will verify the completion of those actions through quarterly follow-up inspections, the results of which will determine when ANO should transition out of Column 4. Pilgrim NRC Oversight and Planned Shutdown In September 2015 the NRC placed Pilgrim in its “multiple/repetitive degraded cornerstone column” (Column 4) of its Reactor Oversight Process Action Matrix due to its finding of continuing weaknesses in Pilgrim’s corrective action program that contributed to repeated unscheduled shutdowns and equipment failures. The preliminary estimate of direct costs of Pilgrim’s response to a planned NRC enhanced inspection ranges from $45 million to $60 million in operation and maintenance expense, including approximately $30 million in 2016, of which $12 million was incurred as of June 30, 2016. The estimate does not include potential capital investment or other costs to address issues that may arise in the inspection. Entergy determined in April 2016 that it intends to refuel Pilgrim in 2017 and then cease operations May 31, 2019. In October 2015, Entergy previously announced its intention to cease operations at Pilgrim because of poor market conditions, reduced revenues, and increased operational costs. Pilgrim currently has approximately 677 MW of Capacity Supply Obligations in ISO New England through May 2019. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the current Presidential administration’s defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Management cannot predict the potential timing or magnitude of future spent fuel fee revisions that may occur. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2016 related to Entergy’s nuclear owner licensee subsidiaries litigation with the DOE. In December 2015 the U.S. Court of Federal Claims issued a judgment in the amount of $81 million in favor of Entergy Nuclear Indian Point 3 and Entergy Nuclear FitzPatrick in the first round Indian Point 3/FitzPatrick damages case, and Entergy received the payment from the U.S. Treasury in June 2016. The effect of recording the Indian Point 3 proceeds was a reduction to plant, other operation and maintenance expense, and depreciation expense. The Indian Point 3 damages award included $45 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $45 million, Entergy recorded $8 million as a reduction to previously-recorded depreciation expense. Entergy reduced its Indian Point 3 plant asset balance by the remaining $37 million . The effect of recording the FitzPatrick proceeds was a reduction to plant and other operation and maintenance expense. The FitzPatrick damages awarded included $32 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $32 million, Entergy recorded an $11 million reduction to bring its remaining FitzPatrick plant asset balance to zero . The remaining $21 million was recorded as a reduction to other operation and maintenance expense because FitzPatrick’s plant asset balance is fully impaired. In April 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $42 million in favor of Entergy Louisiana and against the DOE in the first round River Bend damages case, reserving the issue of cask loading costs pending resolution of the appeal on the same issues in the Entergy Arkansas and System Energy cases. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Louisiana requested payment from the U.S. Treasury of the $42 million in June 2016 and recorded a receivable as of June 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The River Bend damages award included $17 million related to costs previously capitalized, $23 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $17 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its River Bend plant asset balance by the remaining $14 million . In May 2016, Entergy Nuclear Vermont Yankee and the DOE entered into a stipulation agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $19 million in favor of Entergy Nuclear Vermont Yankee and against the DOE in the second round Vermont Yankee damages case. Entergy received payment from the U.S. Treasury in June 2016. The effect of recording the proceeds was a reduction to other operation and maintenance expense and depreciation expense. The damages awarded included $15 million related to costs previously capitalized and $4 million related to costs previously recorded as other operation and maintenance expense. Of the $15 million, Entergy recorded $2 million as a reduction to previously-recorded depreciation expense. The remaining $13 million would have been recorded as a reduction to Vermont Yankee’s plant asset balance, but was recorded as a reduction to other operation and maintenance expense because Vermont Yankee’s plant asset balance is fully impaired. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Conventional Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Louisiana, 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 $30.6 million was incurred as of June 30, 2016, in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. A lesser amount of incremental expenses is expected to be ongoing annually after 2016, until ANO transitions out of Column 4. The NRC completed the supplemental inspection required for ANO’s Column 4 designation in February 2016, and published its inspection report in June 2016. In its inspection report, the NRC concluded that the ANO site is being operated safely and that Entergy understands the depth and breadth of performance concerns associated with ANO’s performance decline. Also in June 2016, the NRC issued a confirmatory action letter to confirm the actions Entergy Arkansas has taken and will continue to take to improve performance at ANO. The NRC will verify the completion of those actions through quarterly follow-up inspections, the results of which will determine when ANO should transition out of Column 4. Pilgrim NRC Oversight and Planned Shutdown In September 2015 the NRC placed Pilgrim in its “multiple/repetitive degraded cornerstone column” (Column 4) of its Reactor Oversight Process Action Matrix due to its finding of continuing weaknesses in Pilgrim’s corrective action program that contributed to repeated unscheduled shutdowns and equipment failures. The preliminary estimate of direct costs of Pilgrim’s response to a planned NRC enhanced inspection ranges from $45 million to $60 million in operation and maintenance expense, including approximately $30 million in 2016, of which $12 million was incurred as of June 30, 2016. The estimate does not include potential capital investment or other costs to address issues that may arise in the inspection. Entergy determined in April 2016 that it intends to refuel Pilgrim in 2017 and then cease operations May 31, 2019. In October 2015, Entergy previously announced its intention to cease operations at Pilgrim because of poor market conditions, reduced revenues, and increased operational costs. Pilgrim currently has approximately 677 MW of Capacity Supply Obligations in ISO New England through May 2019. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the current Presidential administration’s defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Management cannot predict the potential timing or magnitude of future spent fuel fee revisions that may occur. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2016 related to Entergy’s nuclear owner licensee subsidiaries litigation with the DOE. In December 2015 the U.S. Court of Federal Claims issued a judgment in the amount of $81 million in favor of Entergy Nuclear Indian Point 3 and Entergy Nuclear FitzPatrick in the first round Indian Point 3/FitzPatrick damages case, and Entergy received the payment from the U.S. Treasury in June 2016. The effect of recording the Indian Point 3 proceeds was a reduction to plant, other operation and maintenance expense, and depreciation expense. The Indian Point 3 damages award included $45 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $45 million, Entergy recorded $8 million as a reduction to previously-recorded depreciation expense. Entergy reduced its Indian Point 3 plant asset balance by the remaining $37 million . The effect of recording the FitzPatrick proceeds was a reduction to plant and other operation and maintenance expense. The FitzPatrick damages awarded included $32 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $32 million, Entergy recorded an $11 million reduction to bring its remaining FitzPatrick plant asset balance to zero . The remaining $21 million was recorded as a reduction to other operation and maintenance expense because FitzPatrick’s plant asset balance is fully impaired. In April 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $42 million in favor of Entergy Louisiana and against the DOE in the first round River Bend damages case, reserving the issue of cask loading costs pending resolution of the appeal on the same issues in the Entergy Arkansas and System Energy cases. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Louisiana requested payment from the U.S. Treasury of the $42 million in June 2016 and recorded a receivable as of June 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The River Bend damages award included $17 million related to costs previously capitalized, $23 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $17 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its River Bend plant asset balance by the remaining $14 million . In May 2016, Entergy Nuclear Vermont Yankee and the DOE entered into a stipulation agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $19 million in favor of Entergy Nuclear Vermont Yankee and against the DOE in the second round Vermont Yankee damages case. Entergy received payment from the U.S. Treasury in June 2016. The effect of recording the proceeds was a reduction to other operation and maintenance expense and depreciation expense. The damages awarded included $15 million related to costs previously capitalized and $4 million related to costs previously recorded as other operation and maintenance expense. Of the $15 million, Entergy recorded $2 million as a reduction to previously-recorded depreciation expense. The remaining $13 million would have been recorded as a reduction to Vermont Yankee’s plant asset balance, but was recorded as a reduction to other operation and maintenance expense because Vermont Yankee’s plant asset balance is fully impaired. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Conventional Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Louisiana, 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 $30.6 million was incurred as of June 30, 2016, in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. A lesser amount of incremental expenses is expected to be ongoing annually after 2016, until ANO transitions out of Column 4. The NRC completed the supplemental inspection required for ANO’s Column 4 designation in February 2016, and published its inspection report in June 2016. In its inspection report, the NRC concluded that the ANO site is being operated safely and that Entergy understands the depth and breadth of performance concerns associated with ANO’s performance decline. Also in June 2016, the NRC issued a confirmatory action letter to confirm the actions Entergy Arkansas has taken and will continue to take to improve performance at ANO. The NRC will verify the completion of those actions through quarterly follow-up inspections, the results of which will determine when ANO should transition out of Column 4. Pilgrim NRC Oversight and Planned Shutdown In September 2015 the NRC placed Pilgrim in its “multiple/repetitive degraded cornerstone column” (Column 4) of its Reactor Oversight Process Action Matrix due to its finding of continuing weaknesses in Pilgrim’s corrective action program that contributed to repeated unscheduled shutdowns and equipment failures. The preliminary estimate of direct costs of Pilgrim’s response to a planned NRC enhanced inspection ranges from $45 million to $60 million in operation and maintenance expense, including approximately $30 million in 2016, of which $12 million was incurred as of June 30, 2016. The estimate does not include potential capital investment or other costs to address issues that may arise in the inspection. Entergy determined in April 2016 that it intends to refuel Pilgrim in 2017 and then cease operations May 31, 2019. In October 2015, Entergy previously announced its intention to cease operations at Pilgrim because of poor market conditions, reduced revenues, and increased operational costs. Pilgrim currently has approximately 677 MW of Capacity Supply Obligations in ISO New England through May 2019. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the current Presidential administration’s defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Management cannot predict the potential timing or magnitude of future spent fuel fee revisions that may occur. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2016 related to Entergy’s nuclear owner licensee subsidiaries litigation with the DOE. In December 2015 the U.S. Court of Federal Claims issued a judgment in the amount of $81 million in favor of Entergy Nuclear Indian Point 3 and Entergy Nuclear FitzPatrick in the first round Indian Point 3/FitzPatrick damages case, and Entergy received the payment from the U.S. Treasury in June 2016. The effect of recording the Indian Point 3 proceeds was a reduction to plant, other operation and maintenance expense, and depreciation expense. The Indian Point 3 damages award included $45 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $45 million, Entergy recorded $8 million as a reduction to previously-recorded depreciation expense. Entergy reduced its Indian Point 3 plant asset balance by the remaining $37 million . The effect of recording the FitzPatrick proceeds was a reduction to plant and other operation and maintenance expense. The FitzPatrick damages awarded included $32 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $32 million, Entergy recorded an $11 million reduction to bring its remaining FitzPatrick plant asset balance to zero . The remaining $21 million was recorded as a reduction to other operation and maintenance expense because FitzPatrick’s plant asset balance is fully impaired. In April 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $42 million in favor of Entergy Louisiana and against the DOE in the first round River Bend damages case, reserving the issue of cask loading costs pending resolution of the appeal on the same issues in the Entergy Arkansas and System Energy cases. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Louisiana requested payment from the U.S. Treasury of the $42 million in June 2016 and recorded a receivable as of June 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The River Bend damages award included $17 million related to costs previously capitalized, $23 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $17 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its River Bend plant asset balance by the remaining $14 million . In May 2016, Entergy Nuclear Vermont Yankee and the DOE entered into a stipulation agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $19 million in favor of Entergy Nuclear Vermont Yankee and against the DOE in the second round Vermont Yankee damages case. Entergy received payment from the U.S. Treasury in June 2016. The effect of recording the proceeds was a reduction to other operation and maintenance expense and depreciation expense. The damages awarded included $15 million related to costs previously capitalized and $4 million related to costs previously recorded as other operation and maintenance expense. Of the $15 million, Entergy recorded $2 million as a reduction to previously-recorded depreciation expense. The remaining $13 million would have been recorded as a reduction to Vermont Yankee’s plant asset balance, but was recorded as a reduction to other operation and maintenance expense because Vermont Yankee’s plant asset balance is fully impaired. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Conventional Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Louisiana, 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 $30.6 million was incurred as of June 30, 2016, in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. A lesser amount of incremental expenses is expected to be ongoing annually after 2016, until ANO transitions out of Column 4. The NRC completed the supplemental inspection required for ANO’s Column 4 designation in February 2016, and published its inspection report in June 2016. In its inspection report, the NRC concluded that the ANO site is being operated safely and that Entergy understands the depth and breadth of performance concerns associated with ANO’s performance decline. Also in June 2016, the NRC issued a confirmatory action letter to confirm the actions Entergy Arkansas has taken and will continue to take to improve performance at ANO. The NRC will verify the completion of those actions through quarterly follow-up inspections, the results of which will determine when ANO should transition out of Column 4. Pilgrim NRC Oversight and Planned Shutdown In September 2015 the NRC placed Pilgrim in its “multiple/repetitive degraded cornerstone column” (Column 4) of its Reactor Oversight Process Action Matrix due to its finding of continuing weaknesses in Pilgrim’s corrective action program that contributed to repeated unscheduled shutdowns and equipment failures. The preliminary estimate of direct costs of Pilgrim’s response to a planned NRC enhanced inspection ranges from $45 million to $60 million in operation and maintenance expense, including approximately $30 million in 2016, of which $12 million was incurred as of June 30, 2016. The estimate does not include potential capital investment or other costs to address issues that may arise in the inspection. Entergy determined in April 2016 that it intends to refuel Pilgrim in 2017 and then cease operations May 31, 2019. In October 2015, Entergy previously announced its intention to cease operations at Pilgrim because of poor market conditions, reduced revenues, and increased operational costs. Pilgrim currently has approximately 677 MW of Capacity Supply Obligations in ISO New England through May 2019. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the current Presidential administration’s defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Management cannot predict the potential timing or magnitude of future spent fuel fee revisions that may occur. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2016 related to Entergy’s nuclear owner licensee subsidiaries litigation with the DOE. In December 2015 the U.S. Court of Federal Claims issued a judgment in the amount of $81 million in favor of Entergy Nuclear Indian Point 3 and Entergy Nuclear FitzPatrick in the first round Indian Point 3/FitzPatrick damages case, and Entergy received the payment from the U.S. Treasury in June 2016. The effect of recording the Indian Point 3 proceeds was a reduction to plant, other operation and maintenance expense, and depreciation expense. The Indian Point 3 damages award included $45 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $45 million, Entergy recorded $8 million as a reduction to previously-recorded depreciation expense. Entergy reduced its Indian Point 3 plant asset balance by the remaining $37 million . The effect of recording the FitzPatrick proceeds was a reduction to plant and other operation and maintenance expense. The FitzPatrick damages awarded included $32 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $32 million, Entergy recorded an $11 million reduction to bring its remaining FitzPatrick plant asset balance to zero . The remaining $21 million was recorded as a reduction to other operation and maintenance expense because FitzPatrick’s plant asset balance is fully impaired. In April 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $42 million in favor of Entergy Louisiana and against the DOE in the first round River Bend damages case, reserving the issue of cask loading costs pending resolution of the appeal on the same issues in the Entergy Arkansas and System Energy cases. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Louisiana requested payment from the U.S. Treasury of the $42 million in June 2016 and recorded a receivable as of June 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The River Bend damages award included $17 million related to costs previously capitalized, $23 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $17 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its River Bend plant asset balance by the remaining $14 million . In May 2016, Entergy Nuclear Vermont Yankee and the DOE entered into a stipulation agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $19 million in favor of Entergy Nuclear Vermont Yankee and against the DOE in the second round Vermont Yankee damages case. Entergy received payment from the U.S. Treasury in June 2016. The effect of recording the proceeds was a reduction to other operation and maintenance expense and depreciation expense. The damages awarded included $15 million related to costs previously capitalized and $4 million related to costs previously recorded as other operation and maintenance expense. Of the $15 million, Entergy recorded $2 million as a reduction to previously-recorded depreciation expense. The remaining $13 million would have been recorded as a reduction to Vermont Yankee’s plant asset balance, but was recorded as a reduction to other operation and maintenance expense because Vermont Yankee’s plant asset balance is fully impaired. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Conventional Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Louisiana, 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 $30.6 million was incurred as of June 30, 2016, in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. A lesser amount of incremental expenses is expected to be ongoing annually after 2016, until ANO transitions out of Column 4. The NRC completed the supplemental inspection required for ANO’s Column 4 designation in February 2016, and published its inspection report in June 2016. In its inspection report, the NRC concluded that the ANO site is being operated safely and that Entergy understands the depth and breadth of performance concerns associated with ANO’s performance decline. Also in June 2016, the NRC issued a confirmatory action letter to confirm the actions Entergy Arkansas has taken and will continue to take to improve performance at ANO. The NRC will verify the completion of those actions through quarterly follow-up inspections, the results of which will determine when ANO should transition out of Column 4. Pilgrim NRC Oversight and Planned Shutdown In September 2015 the NRC placed Pilgrim in its “multiple/repetitive degraded cornerstone column” (Column 4) of its Reactor Oversight Process Action Matrix due to its finding of continuing weaknesses in Pilgrim’s corrective action program that contributed to repeated unscheduled shutdowns and equipment failures. The preliminary estimate of direct costs of Pilgrim’s response to a planned NRC enhanced inspection ranges from $45 million to $60 million in operation and maintenance expense, including approximately $30 million in 2016, of which $12 million was incurred as of June 30, 2016. The estimate does not include potential capital investment or other costs to address issues that may arise in the inspection. Entergy determined in April 2016 that it intends to refuel Pilgrim in 2017 and then cease operations May 31, 2019. In October 2015, Entergy previously announced its intention to cease operations at Pilgrim because of poor market conditions, reduced revenues, and increased operational costs. Pilgrim currently has approximately 677 MW of Capacity Supply Obligations in ISO New England through May 2019. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the current Presidential administration’s defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Management cannot predict the potential timing or magnitude of future spent fuel fee revisions that may occur. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2016 related to Entergy’s nuclear owner licensee subsidiaries litigation with the DOE. In December 2015 the U.S. Court of Federal Claims issued a judgment in the amount of $81 million in favor of Entergy Nuclear Indian Point 3 and Entergy Nuclear FitzPatrick in the first round Indian Point 3/FitzPatrick damages case, and Entergy received the payment from the U.S. Treasury in June 2016. The effect of recording the Indian Point 3 proceeds was a reduction to plant, other operation and maintenance expense, and depreciation expense. The Indian Point 3 damages award included $45 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $45 million, Entergy recorded $8 million as a reduction to previously-recorded depreciation expense. Entergy reduced its Indian Point 3 plant asset balance by the remaining $37 million . The effect of recording the FitzPatrick proceeds was a reduction to plant and other operation and maintenance expense. The FitzPatrick damages awarded included $32 million related to costs previously capitalized and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $32 million, Entergy recorded an $11 million reduction to bring its remaining FitzPatrick plant asset balance to zero . The remaining $21 million was recorded as a reduction to other operation and maintenance expense because FitzPatrick’s plant asset balance is fully impaired. In April 2016 the U.S. Court of Federal Claims issued a partial judgment in the amount of $42 million in favor of Entergy Louisiana and against the DOE in the first round River Bend damages case, reserving the issue of cask loading costs pending resolution of the appeal on the same issues in the Entergy Arkansas and System Energy cases. The appeals period for the partial judgment has ended with no appeals filed, and Entergy Louisiana requested payment from the U.S. Treasury of the $42 million in June 2016 and recorded a receivable as of June 30, 2016. The primary effects of recording the receivable were reductions to plant, nuclear fuel expense, other operation and maintenance expense, and depreciation expense. The River Bend damages award included $17 million related to costs previously capitalized, $23 million related to costs previously recorded as nuclear fuel expense, and $2 million related to costs previously recorded as other operation and maintenance expense. Of the $17 million, Entergy Louisiana recorded $3 million as a reduction to previously-recorded depreciation expense. Entergy Louisiana reduced its River Bend plant asset balance by the remaining $14 million . In May 2016, Entergy Nuclear Vermont Yankee and the DOE entered into a stipulation agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $19 million in favor of Entergy Nuclear Vermont Yankee and against the DOE in the second round Vermont Yankee damages case. Entergy received payment from the U.S. Treasury in June 2016. The effect of recording the proceeds was a reduction to other operation and maintenance expense and depreciation expense. The damages awarded included $15 million related to costs previously capitalized and $4 million related to costs previously recorded as other operation and maintenance expense. Of the $15 million, Entergy recorded $2 million as a reduction to previously-recorded depreciation expense. The remaining $13 million would have been recorded as a reduction to Vermont Yankee’s plant asset balance, but was recorded as a reduction to other operation and maintenance expense because Vermont Yankee’s plant asset balance is fully impaired. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Conventional Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Louisiana, 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	6 Months Ended
	Jun. 30, 2016
Public Utilities Disclosure [Text Block]	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2016, Entergy Arkansas filed its annual redetermination of the production cost allocation rider, which reflected recovery of the production cost allocation rider true-up adjustment of the 2014 and 2015 unrecovered retail balance in the amount of $1.9 million . Additionally, the redetermined rates reflect the recovery of a $1.9 million System Agreement bandwidth remedy payment resulting from a compliance filing pursuant to the FERC’s December 2015 order related to test year 2009 production costs. The rates for the 2016 production cost allocation rider update became effective with the first billing cycle of July 2016, and rates will be effective through June 2017. Entergy Louisiana In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. The LPSC staff issued its audit report in January 2013. The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million , plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates. The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing. Two parties intervened in the proceeding. A procedural schedule was established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC staff report and any issues raised by intervenors. One intervenor sought further proceedings regarding certain issues it raised in its comments on the LPSC staff report. Entergy Louisiana filed responses to both the LPSC staff report and the issues raised by the intervenor. After conducting additional discovery, in April 2016 the LPSC staff consultant issued its supplemental audit report, which concluded that Entergy Louisiana was not imprudent on the issues raised by the intervenor. A procedural schedule has been established for this proceeding, including an evidentiary hearing in November 2016. In December 2011 the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through 2009. In March 2016 the LPSC staff consultant issued its audit report. In its report, the LPSC staff consultant recommended that Entergy Louisiana refund approximately $8.6 million , plus interest, to customers and realign the recovery of approximately $12.7 million from Entergy Gulf States Louisiana’s fuel adjustment clause to base rates. Entergy Louisiana has recorded a provision for the estimated outcome of this proceeding. A procedural schedule has been established for this proceeding, including a hearing in December 2016. In June 2016 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. In recognition of the business combination that occurred in 2015, the audit notice was issued to Entergy Louisiana and will also include a review of charges to legacy Entergy Gulf States Louisiana customers prior to the business combination. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment and purchased gas adjustment mechanisms for the period from 2012 through 2015. Discovery has not commenced. Entergy Mississippi Entergy Mississippi had a deferred fuel over-recovery balance of $58.3 million as of May 31, 2015, along with an under-recovery balance of $12.3 million under the power management rider. Pursuant to those tariffs, in July 2015, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider to flow through to customers the approximately $46 million net over-recovery over a six-month period. In August 2015 the MPSC approved the interim adjustments effective with September 2015 bills. In November 2015, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included a projected over-recovery balance of $48 million projected through January 31, 2016. In January 2016 the MPSC approved the redetermined annual factor effective February 1, 2016. The MPSC further ordered, however, that due to the significant change in natural gas price forecasts since Entergy Mississippi’s filing in November 2015, Entergy Mississippi shall file a revised fuel factor with the MPSC no later than February 1, 2016. Pursuant to that order, Entergy Mississippi submitted a revised fuel factor. Additionally, because Entergy Mississippi’s projected over-recovery balance for the period ending January 31, 2017 was $68 million , in February 2016, Entergy Mississippi filed for another interim adjustment to the energy cost factor effective April 2016 to flow through to customers the projected over-recovery balance over a six-month period. That interim adjustment was approved by the MPSC in February 2016 effective for April 2016 bills. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in the open proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional $10.9 million in bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. Both appeals are pending, but the appeals do not stay the PUCT’s decision. The federal appeal is scheduled to be heard in December 2016. In April 2016, Entergy Texas filed with the PUCT an application to refund to customers approximately $56.2 million . The refund resulted from (i) $41.8 million of fuel cost recovery over-collections through February 2016, (ii) the $10.9 million in bandwidth remedy payments, discussed above, that Entergy Texas received related to calendar year 2006 production costs, and (iii) $3.5 million in bandwidth remedy payments that Entergy Texas received related to 2006-2008 production costs. In June 2016, Entergy Texas filed an unopposed settlement agreement that added additional over-recovered fuel costs for the months of March and April 2016. The settlement resulted in a $68 million refund. The ALJ approved the refund on an interim basis to be made to most customers over a four-month period beginning with the first billing cycle of July 2016. In July 2016 the PUCT issued an order approving the interim refund. In July 2016, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period April 1, 2013 through March 31, 2016. Under a recent PUCT rule change, a fuel reconciliation is required to be filed at least once every three years and outside of a base rate case filing. During the reconciliation period, Entergy Texas incurred approximately $1.77 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimates an over-recovery balance of approximately $19.3 million , including interest, which Entergy Texas is requesting authority to carry over as the beginning balance for the subsequent reconciliation period beginning Apri1 2016. Entergy Texas also notes, however, that the $19.3 million over collection is currently being refunded to customers as a portion of the interim fuel refund beginning with the first billing cycle of July 2016, discussed above. Entergy Texas also is requesting a prudence finding for each of the fuel-related contracts and arrangements entered into or modified during the reconciliation period that have not be reviewed by the PUCT in a prior proceeding. The PUCT has one year to issue a final order in this proceeding. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC 2015 Rate Case In April 2015, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. The filing notified the APSC of Entergy Arkansas’s intent to implement a formula rate review mechanism pursuant to Arkansas legislation passed in 2015, and requested a retail rate increase of $268.4 million , with a net increase in revenue of $167 million. The filing requested a 10.2% return on common equity. In September 2015 the APSC staff and intervenors filed direct testimony, with the APSC staff recommending a revenue requirement of $217.9 million and a 9.65% return on common equity. In December 2015, Entergy Arkansas, the APSC staff, and certain of the intervenors in the rate case filed with the APSC a joint motion for approval of a settlement of the case that proposed a retail rate increase of approximately $225 million with a net increase in revenue of approximately $133 million ; an authorized return on common equity of 9.75% ; and a formula rate plan tariff that provides a +/- 50 basis point band around the 9.75% allowed return on common equity. A significant portion of the rate increase is related to Entergy Arkansas’s acquisition in March 2016 of Union Power Station Power Block 2 for a base purchase price of $237 million , subject to closing adjustments. The settlement agreement also provided for amortization over a 10-year period of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance. A settlement hearing was held in January 2016. In February 2016 the APSC approved the settlement with one exception that would reduce the retail rate increase proposed in the settlement by $5 million . The settling parties agreed to the APSC modifications in February 2016. The new rates were effective February 24, 2016 and began billing with the first billing cycle of April 2016. In March 2016, Entergy Arkansas made a compliance filing regarding the new rates that included an interim base rate adjustment surcharge, effective with the first billing cycle of April 2016, to recover the incremental revenue requirement for the period February 24, 2016 through March 31, 2016. The interim base rate adjustment surcharge will recover a total of $21.1 million over the nine-month period from April 2016 through December 2016. 2016 Formula Rate Plan Filing In July 2016, Entergy Arkansas filed with the APSC its 2016 Entergy Arkansas formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2017 test year to be below the formula rate plan bandwidth. The filing requests a $68 million rate increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . Entergy Arkansas requested an order approving its proposed formula rate plan adjustment by December 9, 2016. If a final order is not issued by this date, the proposed formula rate plan adjustment will become effective December 30, 2016, subject to refund. Filings with the LPSC Retail Rates - Electric 2015 Formula Rate Plan Filing In May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. The evaluation report reflects an earned return on common equity of 9.07% . As such, no adjustment to base formula rate plan revenue is required. The following other adjustments, however, are required under the formula rate plan: an increase in the legacy Entergy Louisiana additional capacity mechanism of $14.2 million ; a separate increase in legacy Entergy Louisiana revenue of $10 million primarily to reflect the effects of the termination of the System Agreement; an increase in the legacy Entergy Gulf States Louisiana additional capacity mechanism of $0.5 million ; a decrease in legacy Entergy Gulf States Louisiana revenue of $58.7 million primarily to reflect the effects of the termination of the System Agreement; and an increase of $11 million to the MISO cost recovery mechanism. Rates are scheduled to be implemented with the first billing cycle of September 2016, subject to refund. 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 had questioned the warranty coverage for one element of the project. In March 2016, Entergy Louisiana and the LPSC staff filed a joint motion to suspend the procedural schedule pending the filing of an uncontested joint stipulated settlement. Union Power Station As discussed in the Form 10-K, in October 2015 the LPSC approved a settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station. In March 2016, Entergy Louisiana acquired Power Blocks 3 and 4 of Union Power Station for an aggregate purchase price of approximately $474 million and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. As a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. Parties have requested further proceedings on the prudence of Entergy Louisiana’s decision to deactivate Willow Glen 2 and 4. This matter is pending before an ALJ, and a hearing has been scheduled in March 2017 to determine, under applicable law, whether Willow Glen 2 and 4 units should be returned to service. Retail Rates - Gas In January 2016, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2015. The filing showed an earned return on common equity of 10.22% , which is within the authorized bandwidth, therefore requiring no change in rates. In March 2016 the LPSC staff issued its report stating that the 2015 gas rate stabilization plan filing is in compliance with the exception of several issues that require additional information, explanation, or clarification for which the LPSC staff has reserved the right to further review. In July 2016 the parties to the proceeding filed an unopposed joint report and motion for entry of order accepting report that indicates no outstanding issues remain in the filing. Absent approval of an extension by the LPSC, test year 2015 is the final year under the current gas rate stabilization plan. In February 2016, however, Entergy Louisiana filed a motion requesting to extend the term of the gas rate stabilization plan for an additional three-year term. A procedural schedule has been established, including a hearing in November 2016. Filings with the MPSC In March 2016, Entergy Mississippi submitted its formula rate plan 2016 test year filing showing Entergy Mississippi’s projected earned return for the 2016 calendar year to be below the formula rate plan bandwidth. The filing showed a $32.6 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 9.96% , within the formula rate plan bandwidth. In June 2016 the MPSC approved Entergy Mississippi’s joint stipulation with the Mississippi Public Utilities Staff. The joint stipulation provided for a total revenue increase of $23.7 million . The revenue increase includes a $19.4 million increase through the formula rate plan, resulting in a return on common equity point of adjustment of 10.07% . The revenue increase also includes $4.3 million in incremental ad valorem tax expenses to be collected through an updated ad valorem tax adjustment rider. The revenue increase and ad valorem tax adjustment rider were effective with the July 2016 bills. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the terms of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6, the revenue requirement associated with the purchase of Power Block 1 of the Union Power Station, and a credit to customers of $400 thousand monthly beginning June 2016 in recognition of the decrease in other operation and maintenance expenses that would result with the deactivation of Michoud Units 2 and 3. In March 2016, Entergy New Orleans purchased Power Block 1 of the Union Power Station for approximately $237 million and initiated recovery of these costs with March 2016 bills. In July 2016, Entergy New Orleans and the City Council Utility Committee agreed to a temporary increase in the credit to customers to a total of $1.4 million monthly for August 2016 through December 2016. Internal Restructuring In July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring which would result in the transfer of substantially all of the assets and operations of Entergy New Orleans to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval of the City Council and the FERC. If the application is approved by the City Council in 2016, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2016 and 2017. The filing with the FERC has not yet been made, but if the restructuring is approved by the FERC by December 31, 2018, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2018, 2019, and 2020. If City Council and FERC approvals are obtained, Entergy New Orleans expects the restructuring will be consummated by December 31, 2017. It is currently contemplated that Entergy New Orleans would undertake a multi-step restructuring, which would include the following: • Entergy New Orleans would redeem its outstanding preferred stock at a price of approximately $21 million , which includes an expected call premium of approximately $819,000 , plus any accumulated and unpaid dividends. • Entergy New Orleans would convert from a Louisiana corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy New Orleans will allocate substantially all of its assets to a new subsidiary, Entergy New Orleans Power, LLC, a Texas limited liability company (Entergy New Orleans Power), and Entergy New Orleans Power will assume substantially all of the liabilities of Entergy New Orleans, in a transaction regarded as a merger under the TXBOC. Entergy New Orleans will remain in existence and hold the membership interests in Entergy New Orleans Power. • Entergy New Orleans will contribute the membership interests in Entergy New Orleans Power to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy New Orleans Power will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC. • Entergy New Orleans will change its name to Entergy New Orleans Holdings, Inc., and Entergy New Orleans Power will then change its name to Entergy New Orleans, LLC. Upon the completion of the restructuring, Entergy New Orleans, LLC will hold substantially all of the assets, and will have assumed substantially all of the liabilities, of Entergy New Orleans. Entergy New Orleans may modify or supplement the steps to be taken to effectuate the restructuring. 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 petitioned the Texas Supreme Court to hear its appeal of the Third Court’s ruling. That petition is pending. Other Filings In September 2015, Entergy Texas filed for a transmission cost recovery factor (TCRF) 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 April 2016 the PUCT voted to allow Entergy Texas’s TCRF rates to become effective as of April 14, 2016 when those rates are finally approved, but did not otherwise address the proposal for decision. 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. In June 2016 the PUCT indicated that it would take up in a future rulemaking project the issue of whether a load growth adjustment should apply to a TCRF. In July 2016 the PUCT issued an order generally accepting the proposal for decision but declining to adjust the TCRF baseline in two instances as recommended by the ALJ, which results in a total annual allowance of approximately $10.5 million . The PUCT also ordered its staff and Entergy Texas to track all spare autotransformer transfers going forward so that it could address the appropriate accounting treatment and prudence of such transfers in Entergy Texas’s next base rate case. System Agreement Cost Equalization Proceedings Rough Production Cost Equalization Rates Consolidated 2011, 2012, 2013, and 2014 Rate Filing Proceedings As discussed in the Form 10-K, in December 2014 the FERC consolidated the 2011, 2012, 2013, and 2014 rate filings for settlement and hearing procedures. In May 2015, Entergy filed direct testimony in the consolidated rate filings and the LPSC filed direct testimony concerning its complaint proceeding that is consolidated with the rate filings, challenging certain components of the pending bandwidth calculations for prior years. In July 2015 the parties filed direct and answering testimony. In August and September 2015 the parties filed additional rounds of testimony in the consolidated hearing for the 2011, 2012, 2013, and 2014 rate filings. In October 2015 the LPSC withdrew its testimony challenging the accounting for joint account sales of energy. The hearings occurred in November 2015, and an initial decision from the ALJ was issued in July 2016. In the initial decision, the ALJ generally agreed with Entergy’s bandwidth calculations with one exception on the accounting related to the Waterford 3 sale/leaseback. Briefs are due in August and September 2016. 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. The settlement is pending at the FERC. 2016 Rate Filing Based on Calendar Year 2015 Production Costs In May 2016, Entergy filed with the FERC the 2016 rates in accordance with the FERC’s orders in the System Agreement proceeding. The filing showed that no payments and receipts were required in 2016 to implement the FERC’s remedy based on calendar year 2015 production costs. The LPSC and City Council intervened in the proceeding. 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. In May 2016 the LPSC filed a request for rehearing of the FERC’s April 2016 order. 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. In May 2016 a procedural schedule was established with a hearing in May
Entergy Arkansas [Member]
Public Utilities Disclosure [Text Block]	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2016, Entergy Arkansas filed its annual redetermination of the production cost allocation rider, which reflected recovery of the production cost allocation rider true-up adjustment of the 2014 and 2015 unrecovered retail balance in the amount of $1.9 million . Additionally, the redetermined rates reflect the recovery of a $1.9 million System Agreement bandwidth remedy payment resulting from a compliance filing pursuant to the FERC’s December 2015 order related to test year 2009 production costs. The rates for the 2016 production cost allocation rider update became effective with the first billing cycle of July 2016, and rates will be effective through June 2017. Entergy Louisiana In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. The LPSC staff issued its audit report in January 2013. The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million , plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates. The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing. Two parties intervened in the proceeding. A procedural schedule was established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC staff report and any issues raised by intervenors. One intervenor sought further proceedings regarding certain issues it raised in its comments on the LPSC staff report. Entergy Louisiana filed responses to both the LPSC staff report and the issues raised by the intervenor. After conducting additional discovery, in April 2016 the LPSC staff consultant issued its supplemental audit report, which concluded that Entergy Louisiana was not imprudent on the issues raised by the intervenor. A procedural schedule has been established for this proceeding, including an evidentiary hearing in November 2016. In December 2011 the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through 2009. In March 2016 the LPSC staff consultant issued its audit report. In its report, the LPSC staff consultant recommended that Entergy Louisiana refund approximately $8.6 million , plus interest, to customers and realign the recovery of approximately $12.7 million from Entergy Gulf States Louisiana’s fuel adjustment clause to base rates. Entergy Louisiana has recorded a provision for the estimated outcome of this proceeding. A procedural schedule has been established for this proceeding, including a hearing in December 2016. In June 2016 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. In recognition of the business combination that occurred in 2015, the audit notice was issued to Entergy Louisiana and will also include a review of charges to legacy Entergy Gulf States Louisiana customers prior to the business combination. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment and purchased gas adjustment mechanisms for the period from 2012 through 2015. Discovery has not commenced. Entergy Mississippi Entergy Mississippi had a deferred fuel over-recovery balance of $58.3 million as of May 31, 2015, along with an under-recovery balance of $12.3 million under the power management rider. Pursuant to those tariffs, in July 2015, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider to flow through to customers the approximately $46 million net over-recovery over a six-month period. In August 2015 the MPSC approved the interim adjustments effective with September 2015 bills. In November 2015, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included a projected over-recovery balance of $48 million projected through January 31, 2016. In January 2016 the MPSC approved the redetermined annual factor effective February 1, 2016. The MPSC further ordered, however, that due to the significant change in natural gas price forecasts since Entergy Mississippi’s filing in November 2015, Entergy Mississippi shall file a revised fuel factor with the MPSC no later than February 1, 2016. Pursuant to that order, Entergy Mississippi submitted a revised fuel factor. Additionally, because Entergy Mississippi’s projected over-recovery balance for the period ending January 31, 2017 was $68 million , in February 2016, Entergy Mississippi filed for another interim adjustment to the energy cost factor effective April 2016 to flow through to customers the projected over-recovery balance over a six-month period. That interim adjustment was approved by the MPSC in February 2016 effective for April 2016 bills. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in the open proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional $10.9 million in bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. Both appeals are pending, but the appeals do not stay the PUCT’s decision. The federal appeal is scheduled to be heard in December 2016. In April 2016, Entergy Texas filed with the PUCT an application to refund to customers approximately $56.2 million . The refund resulted from (i) $41.8 million of fuel cost recovery over-collections through February 2016, (ii) the $10.9 million in bandwidth remedy payments, discussed above, that Entergy Texas received related to calendar year 2006 production costs, and (iii) $3.5 million in bandwidth remedy payments that Entergy Texas received related to 2006-2008 production costs. In June 2016, Entergy Texas filed an unopposed settlement agreement that added additional over-recovered fuel costs for the months of March and April 2016. The settlement resulted in a $68 million refund. The ALJ approved the refund on an interim basis to be made to most customers over a four-month period beginning with the first billing cycle of July 2016. In July 2016 the PUCT issued an order approving the interim refund. In July 2016, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period April 1, 2013 through March 31, 2016. Under a recent PUCT rule change, a fuel reconciliation is required to be filed at least once every three years and outside of a base rate case filing. During the reconciliation period, Entergy Texas incurred approximately $1.77 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimates an over-recovery balance of approximately $19.3 million , including interest, which Entergy Texas is requesting authority to carry over as the beginning balance for the subsequent reconciliation period beginning Apri1 2016. Entergy Texas also notes, however, that the $19.3 million over collection is currently being refunded to customers as a portion of the interim fuel refund beginning with the first billing cycle of July 2016, discussed above. Entergy Texas also is requesting a prudence finding for each of the fuel-related contracts and arrangements entered into or modified during the reconciliation period that have not be reviewed by the PUCT in a prior proceeding. The PUCT has one year to issue a final order in this proceeding. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC 2015 Rate Case In April 2015, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. The filing notified the APSC of Entergy Arkansas’s intent to implement a formula rate review mechanism pursuant to Arkansas legislation passed in 2015, and requested a retail rate increase of $268.4 million , with a net increase in revenue of $167 million. The filing requested a 10.2% return on common equity. In September 2015 the APSC staff and intervenors filed direct testimony, with the APSC staff recommending a revenue requirement of $217.9 million and a 9.65% return on common equity. In December 2015, Entergy Arkansas, the APSC staff, and certain of the intervenors in the rate case filed with the APSC a joint motion for approval of a settlement of the case that proposed a retail rate increase of approximately $225 million with a net increase in revenue of approximately $133 million ; an authorized return on common equity of 9.75% ; and a formula rate plan tariff that provides a +/- 50 basis point band around the 9.75% allowed return on common equity. A significant portion of the rate increase is related to Entergy Arkansas’s acquisition in March 2016 of Union Power Station Power Block 2 for a base purchase price of $237 million , subject to closing adjustments. The settlement agreement also provided for amortization over a 10-year period of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance. A settlement hearing was held in January 2016. In February 2016 the APSC approved the settlement with one exception that would reduce the retail rate increase proposed in the settlement by $5 million . The settling parties agreed to the APSC modifications in February 2016. The new rates were effective February 24, 2016 and began billing with the first billing cycle of April 2016. In March 2016, Entergy Arkansas made a compliance filing regarding the new rates that included an interim base rate adjustment surcharge, effective with the first billing cycle of April 2016, to recover the incremental revenue requirement for the period February 24, 2016 through March 31, 2016. The interim base rate adjustment surcharge will recover a total of $21.1 million over the nine-month period from April 2016 through December 2016. 2016 Formula Rate Plan Filing In July 2016, Entergy Arkansas filed with the APSC its 2016 Entergy Arkansas formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2017 test year to be below the formula rate plan bandwidth. The filing requests a $68 million rate increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . Entergy Arkansas requested an order approving its proposed formula rate plan adjustment by December 9, 2016. If a final order is not issued by this date, the proposed formula rate plan adjustment will become effective December 30, 2016, subject to refund. Filings with the LPSC Retail Rates - Electric 2015 Formula Rate Plan Filing In May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. The evaluation report reflects an earned return on common equity of 9.07% . As such, no adjustment to base formula rate plan revenue is required. The following other adjustments, however, are required under the formula rate plan: an increase in the legacy Entergy Louisiana additional capacity mechanism of $14.2 million ; a separate increase in legacy Entergy Louisiana revenue of $10 million primarily to reflect the effects of the termination of the System Agreement; an increase in the legacy Entergy Gulf States Louisiana additional capacity mechanism of $0.5 million ; a decrease in legacy Entergy Gulf States Louisiana revenue of $58.7 million primarily to reflect the effects of the termination of the System Agreement; and an increase of $11 million to the MISO cost recovery mechanism. Rates are scheduled to be implemented with the first billing cycle of September 2016, subject to refund. 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 had questioned the warranty coverage for one element of the project. In March 2016, Entergy Louisiana and the LPSC staff filed a joint motion to suspend the procedural schedule pending the filing of an uncontested joint stipulated settlement. Union Power Station As discussed in the Form 10-K, in October 2015 the LPSC approved a settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station. In March 2016, Entergy Louisiana acquired Power Blocks 3 and 4 of Union Power Station for an aggregate purchase price of approximately $474 million and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. As a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. Parties have requested further proceedings on the prudence of Entergy Louisiana’s decision to deactivate Willow Glen 2 and 4. This matter is pending before an ALJ, and a hearing has been scheduled in March 2017 to determine, under applicable law, whether Willow Glen 2 and 4 units should be returned to service. Retail Rates - Gas In January 2016, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2015. The filing showed an earned return on common equity of 10.22% , which is within the authorized bandwidth, therefore requiring no change in rates. In March 2016 the LPSC staff issued its report stating that the 2015 gas rate stabilization plan filing is in compliance with the exception of several issues that require additional information, explanation, or clarification for which the LPSC staff has reserved the right to further review. In July 2016 the parties to the proceeding filed an unopposed joint report and motion for entry of order accepting report that indicates no outstanding issues remain in the filing. Absent approval of an extension by the LPSC, test year 2015 is the final year under the current gas rate stabilization plan. In February 2016, however, Entergy Louisiana filed a motion requesting to extend the term of the gas rate stabilization plan for an additional three-year term. A procedural schedule has been established, including a hearing in November 2016. Filings with the MPSC In March 2016, Entergy Mississippi submitted its formula rate plan 2016 test year filing showing Entergy Mississippi’s projected earned return for the 2016 calendar year to be below the formula rate plan bandwidth. The filing showed a $32.6 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 9.96% , within the formula rate plan bandwidth. In June 2016 the MPSC approved Entergy Mississippi’s joint stipulation with the Mississippi Public Utilities Staff. The joint stipulation provided for a total revenue increase of $23.7 million . The revenue increase includes a $19.4 million increase through the formula rate plan, resulting in a return on common equity point of adjustment of 10.07% . The revenue increase also includes $4.3 million in incremental ad valorem tax expenses to be collected through an updated ad valorem tax adjustment rider. The revenue increase and ad valorem tax adjustment rider were effective with the July 2016 bills. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the terms of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6, the revenue requirement associated with the purchase of Power Block 1 of the Union Power Station, and a credit to customers of $400 thousand monthly beginning June 2016 in recognition of the decrease in other operation and maintenance expenses that would result with the deactivation of Michoud Units 2 and 3. In March 2016, Entergy New Orleans purchased Power Block 1 of the Union Power Station for approximately $237 million and initiated recovery of these costs with March 2016 bills. In July 2016, Entergy New Orleans and the City Council Utility Committee agreed to a temporary increase in the credit to customers to a total of $1.4 million monthly for August 2016 through December 2016. Internal Restructuring In July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring which would result in the transfer of substantially all of the assets and operations of Entergy New Orleans to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval of the City Council and the FERC. If the application is approved by the City Council in 2016, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2016 and 2017. The filing with the FERC has not yet been made, but if the restructuring is approved by the FERC by December 31, 2018, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2018, 2019, and 2020. If City Council and FERC approvals are obtained, Entergy New Orleans expects the restructuring will be consummated by December 31, 2017. It is currently contemplated that Entergy New Orleans would undertake a multi-step restructuring, which would include the following: • Entergy New Orleans would redeem its outstanding preferred stock at a price of approximately $21 million , which includes an expected call premium of approximately $819,000 , plus any accumulated and unpaid dividends. • Entergy New Orleans would convert from a Louisiana corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy New Orleans will allocate substantially all of its assets to a new subsidiary, Entergy New Orleans Power, LLC, a Texas limited liability company (Entergy New Orleans Power), and Entergy New Orleans Power will assume substantially all of the liabilities of Entergy New Orleans, in a transaction regarded as a merger under the TXBOC. Entergy New Orleans will remain in existence and hold the membership interests in Entergy New Orleans Power. • Entergy New Orleans will contribute the membership interests in Entergy New Orleans Power to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy New Orleans Power will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC. • Entergy New Orleans will change its name to Entergy New Orleans Holdings, Inc., and Entergy New Orleans Power will then change its name to Entergy New Orleans, LLC. Upon the completion of the restructuring, Entergy New Orleans, LLC will hold substantially all of the assets, and will have assumed substantially all of the liabilities, of Entergy New Orleans. Entergy New Orleans may modify or supplement the steps to be taken to effectuate the restructuring. 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 petitioned the Texas Supreme Court to hear its appeal of the Third Court’s ruling. That petition is pending. Other Filings In September 2015, Entergy Texas filed for a transmission cost recovery factor (TCRF) 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 April 2016 the PUCT voted to allow Entergy Texas’s TCRF rates to become effective as of April 14, 2016 when those rates are finally approved, but did not otherwise address the proposal for decision. 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. In June 2016 the PUCT indicated that it would take up in a future rulemaking project the issue of whether a load growth adjustment should apply to a TCRF. In July 2016 the PUCT issued an order generally accepting the proposal for decision but declining to adjust the TCRF baseline in two instances as recommended by the ALJ, which results in a total annual allowance of approximately $10.5 million . The PUCT also ordered its staff and Entergy Texas to track all spare autotransformer transfers going forward so that it could address the appropriate accounting treatment and prudence of such transfers in Entergy Texas’s next base rate case. System Agreement Cost Equalization Proceedings Rough Production Cost Equalization Rates Consolidated 2011, 2012, 2013, and 2014 Rate Filing Proceedings As discussed in the Form 10-K, in December 2014 the FERC consolidated the 2011, 2012, 2013, and 2014 rate filings for settlement and hearing procedures. In May 2015, Entergy filed direct testimony in the consolidated rate filings and the LPSC filed direct testimony concerning its complaint proceeding that is consolidated with the rate filings, challenging certain components of the pending bandwidth calculations for prior years. In July 2015 the parties filed direct and answering testimony. In August and September 2015 the parties filed additional rounds of testimony in the consolidated hearing for the 2011, 2012, 2013, and 2014 rate filings. In October 2015 the LPSC withdrew its testimony challenging the accounting for joint account sales of energy. The hearings occurred in November 2015, and an initial decision from the ALJ was issued in July 2016. In the initial decision, the ALJ generally agreed with Entergy’s bandwidth calculations with one exception on the accounting related to the Waterford 3 sale/leaseback. Briefs are due in August and September 2016. 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. The settlement is pending at the FERC. 2016 Rate Filing Based on Calendar Year 2015 Production Costs In May 2016, Entergy filed with the FERC the 2016 rates in accordance with the FERC’s orders in the System Agreement proceeding. The filing showed that no payments and receipts were required in 2016 to implement the FERC’s remedy based on calendar year 2015 production costs. The LPSC and City Council intervened in the proceeding. 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. In May 2016 the LPSC filed a request for rehearing of the FERC’s April 2016 order. 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. In May 2016 a procedural schedule was established with a hearing in May
Entergy Louisiana [Member]
Public Utilities Disclosure [Text Block]	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2016, Entergy Arkansas filed its annual redetermination of the production cost allocation rider, which reflected recovery of the production cost allocation rider true-up adjustment of the 2014 and 2015 unrecovered retail balance in the amount of $1.9 million . Additionally, the redetermined rates reflect the recovery of a $1.9 million System Agreement bandwidth remedy payment resulting from a compliance filing pursuant to the FERC’s December 2015 order related to test year 2009 production costs. The rates for the 2016 production cost allocation rider update became effective with the first billing cycle of July 2016, and rates will be effective through June 2017. Entergy Louisiana In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. The LPSC staff issued its audit report in January 2013. The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million , plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates. The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing. Two parties intervened in the proceeding. A procedural schedule was established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC staff report and any issues raised by intervenors. One intervenor sought further proceedings regarding certain issues it raised in its comments on the LPSC staff report. Entergy Louisiana filed responses to both the LPSC staff report and the issues raised by the intervenor. After conducting additional discovery, in April 2016 the LPSC staff consultant issued its supplemental audit report, which concluded that Entergy Louisiana was not imprudent on the issues raised by the intervenor. A procedural schedule has been established for this proceeding, including an evidentiary hearing in November 2016. In December 2011 the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through 2009. In March 2016 the LPSC staff consultant issued its audit report. In its report, the LPSC staff consultant recommended that Entergy Louisiana refund approximately $8.6 million , plus interest, to customers and realign the recovery of approximately $12.7 million from Entergy Gulf States Louisiana’s fuel adjustment clause to base rates. Entergy Louisiana has recorded a provision for the estimated outcome of this proceeding. A procedural schedule has been established for this proceeding, including a hearing in December 2016. In June 2016 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. In recognition of the business combination that occurred in 2015, the audit notice was issued to Entergy Louisiana and will also include a review of charges to legacy Entergy Gulf States Louisiana customers prior to the business combination. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment and purchased gas adjustment mechanisms for the period from 2012 through 2015. Discovery has not commenced. Entergy Mississippi Entergy Mississippi had a deferred fuel over-recovery balance of $58.3 million as of May 31, 2015, along with an under-recovery balance of $12.3 million under the power management rider. Pursuant to those tariffs, in July 2015, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider to flow through to customers the approximately $46 million net over-recovery over a six-month period. In August 2015 the MPSC approved the interim adjustments effective with September 2015 bills. In November 2015, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included a projected over-recovery balance of $48 million projected through January 31, 2016. In January 2016 the MPSC approved the redetermined annual factor effective February 1, 2016. The MPSC further ordered, however, that due to the significant change in natural gas price forecasts since Entergy Mississippi’s filing in November 2015, Entergy Mississippi shall file a revised fuel factor with the MPSC no later than February 1, 2016. Pursuant to that order, Entergy Mississippi submitted a revised fuel factor. Additionally, because Entergy Mississippi’s projected over-recovery balance for the period ending January 31, 2017 was $68 million , in February 2016, Entergy Mississippi filed for another interim adjustment to the energy cost factor effective April 2016 to flow through to customers the projected over-recovery balance over a six-month period. That interim adjustment was approved by the MPSC in February 2016 effective for April 2016 bills. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in the open proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional $10.9 million in bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. Both appeals are pending, but the appeals do not stay the PUCT’s decision. The federal appeal is scheduled to be heard in December 2016. In April 2016, Entergy Texas filed with the PUCT an application to refund to customers approximately $56.2 million . The refund resulted from (i) $41.8 million of fuel cost recovery over-collections through February 2016, (ii) the $10.9 million in bandwidth remedy payments, discussed above, that Entergy Texas received related to calendar year 2006 production costs, and (iii) $3.5 million in bandwidth remedy payments that Entergy Texas received related to 2006-2008 production costs. In June 2016, Entergy Texas filed an unopposed settlement agreement that added additional over-recovered fuel costs for the months of March and April 2016. The settlement resulted in a $68 million refund. The ALJ approved the refund on an interim basis to be made to most customers over a four-month period beginning with the first billing cycle of July 2016. In July 2016 the PUCT issued an order approving the interim refund. In July 2016, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period April 1, 2013 through March 31, 2016. Under a recent PUCT rule change, a fuel reconciliation is required to be filed at least once every three years and outside of a base rate case filing. During the reconciliation period, Entergy Texas incurred approximately $1.77 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimates an over-recovery balance of approximately $19.3 million , including interest, which Entergy Texas is requesting authority to carry over as the beginning balance for the subsequent reconciliation period beginning Apri1 2016. Entergy Texas also notes, however, that the $19.3 million over collection is currently being refunded to customers as a portion of the interim fuel refund beginning with the first billing cycle of July 2016, discussed above. Entergy Texas also is requesting a prudence finding for each of the fuel-related contracts and arrangements entered into or modified during the reconciliation period that have not be reviewed by the PUCT in a prior proceeding. The PUCT has one year to issue a final order in this proceeding. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC 2015 Rate Case In April 2015, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. The filing notified the APSC of Entergy Arkansas’s intent to implement a formula rate review mechanism pursuant to Arkansas legislation passed in 2015, and requested a retail rate increase of $268.4 million , with a net increase in revenue of $167 million. The filing requested a 10.2% return on common equity. In September 2015 the APSC staff and intervenors filed direct testimony, with the APSC staff recommending a revenue requirement of $217.9 million and a 9.65% return on common equity. In December 2015, Entergy Arkansas, the APSC staff, and certain of the intervenors in the rate case filed with the APSC a joint motion for approval of a settlement of the case that proposed a retail rate increase of approximately $225 million with a net increase in revenue of approximately $133 million ; an authorized return on common equity of 9.75% ; and a formula rate plan tariff that provides a +/- 50 basis point band around the 9.75% allowed return on common equity. A significant portion of the rate increase is related to Entergy Arkansas’s acquisition in March 2016 of Union Power Station Power Block 2 for a base purchase price of $237 million , subject to closing adjustments. The settlement agreement also provided for amortization over a 10-year period of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance. A settlement hearing was held in January 2016. In February 2016 the APSC approved the settlement with one exception that would reduce the retail rate increase proposed in the settlement by $5 million . The settling parties agreed to the APSC modifications in February 2016. The new rates were effective February 24, 2016 and began billing with the first billing cycle of April 2016. In March 2016, Entergy Arkansas made a compliance filing regarding the new rates that included an interim base rate adjustment surcharge, effective with the first billing cycle of April 2016, to recover the incremental revenue requirement for the period February 24, 2016 through March 31, 2016. The interim base rate adjustment surcharge will recover a total of $21.1 million over the nine-month period from April 2016 through December 2016. 2016 Formula Rate Plan Filing In July 2016, Entergy Arkansas filed with the APSC its 2016 Entergy Arkansas formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2017 test year to be below the formula rate plan bandwidth. The filing requests a $68 million rate increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . Entergy Arkansas requested an order approving its proposed formula rate plan adjustment by December 9, 2016. If a final order is not issued by this date, the proposed formula rate plan adjustment will become effective December 30, 2016, subject to refund. Filings with the LPSC Retail Rates - Electric 2015 Formula Rate Plan Filing In May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. The evaluation report reflects an earned return on common equity of 9.07% . As such, no adjustment to base formula rate plan revenue is required. The following other adjustments, however, are required under the formula rate plan: an increase in the legacy Entergy Louisiana additional capacity mechanism of $14.2 million ; a separate increase in legacy Entergy Louisiana revenue of $10 million primarily to reflect the effects of the termination of the System Agreement; an increase in the legacy Entergy Gulf States Louisiana additional capacity mechanism of $0.5 million ; a decrease in legacy Entergy Gulf States Louisiana revenue of $58.7 million primarily to reflect the effects of the termination of the System Agreement; and an increase of $11 million to the MISO cost recovery mechanism. Rates are scheduled to be implemented with the first billing cycle of September 2016, subject to refund. 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 had questioned the warranty coverage for one element of the project. In March 2016, Entergy Louisiana and the LPSC staff filed a joint motion to suspend the procedural schedule pending the filing of an uncontested joint stipulated settlement. Union Power Station As discussed in the Form 10-K, in October 2015 the LPSC approved a settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station. In March 2016, Entergy Louisiana acquired Power Blocks 3 and 4 of Union Power Station for an aggregate purchase price of approximately $474 million and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. As a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. Parties have requested further proceedings on the prudence of Entergy Louisiana’s decision to deactivate Willow Glen 2 and 4. This matter is pending before an ALJ, and a hearing has been scheduled in March 2017 to determine, under applicable law, whether Willow Glen 2 and 4 units should be returned to service. Retail Rates - Gas In January 2016, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2015. The filing showed an earned return on common equity of 10.22% , which is within the authorized bandwidth, therefore requiring no change in rates. In March 2016 the LPSC staff issued its report stating that the 2015 gas rate stabilization plan filing is in compliance with the exception of several issues that require additional information, explanation, or clarification for which the LPSC staff has reserved the right to further review. In July 2016 the parties to the proceeding filed an unopposed joint report and motion for entry of order accepting report that indicates no outstanding issues remain in the filing. Absent approval of an extension by the LPSC, test year 2015 is the final year under the current gas rate stabilization plan. In February 2016, however, Entergy Louisiana filed a motion requesting to extend the term of the gas rate stabilization plan for an additional three-year term. A procedural schedule has been established, including a hearing in November 2016. Filings with the MPSC In March 2016, Entergy Mississippi submitted its formula rate plan 2016 test year filing showing Entergy Mississippi’s projected earned return for the 2016 calendar year to be below the formula rate plan bandwidth. The filing showed a $32.6 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 9.96% , within the formula rate plan bandwidth. In June 2016 the MPSC approved Entergy Mississippi’s joint stipulation with the Mississippi Public Utilities Staff. The joint stipulation provided for a total revenue increase of $23.7 million . The revenue increase includes a $19.4 million increase through the formula rate plan, resulting in a return on common equity point of adjustment of 10.07% . The revenue increase also includes $4.3 million in incremental ad valorem tax expenses to be collected through an updated ad valorem tax adjustment rider. The revenue increase and ad valorem tax adjustment rider were effective with the July 2016 bills. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the terms of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6, the revenue requirement associated with the purchase of Power Block 1 of the Union Power Station, and a credit to customers of $400 thousand monthly beginning June 2016 in recognition of the decrease in other operation and maintenance expenses that would result with the deactivation of Michoud Units 2 and 3. In March 2016, Entergy New Orleans purchased Power Block 1 of the Union Power Station for approximately $237 million and initiated recovery of these costs with March 2016 bills. In July 2016, Entergy New Orleans and the City Council Utility Committee agreed to a temporary increase in the credit to customers to a total of $1.4 million monthly for August 2016 through December 2016. Internal Restructuring In July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring which would result in the transfer of substantially all of the assets and operations of Entergy New Orleans to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval of the City Council and the FERC. If the application is approved by the City Council in 2016, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2016 and 2017. The filing with the FERC has not yet been made, but if the restructuring is approved by the FERC by December 31, 2018, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2018, 2019, and 2020. If City Council and FERC approvals are obtained, Entergy New Orleans expects the restructuring will be consummated by December 31, 2017. It is currently contemplated that Entergy New Orleans would undertake a multi-step restructuring, which would include the following: • Entergy New Orleans would redeem its outstanding preferred stock at a price of approximately $21 million , which includes an expected call premium of approximately $819,000 , plus any accumulated and unpaid dividends. • Entergy New Orleans would convert from a Louisiana corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy New Orleans will allocate substantially all of its assets to a new subsidiary, Entergy New Orleans Power, LLC, a Texas limited liability company (Entergy New Orleans Power), and Entergy New Orleans Power will assume substantially all of the liabilities of Entergy New Orleans, in a transaction regarded as a merger under the TXBOC. Entergy New Orleans will remain in existence and hold the membership interests in Entergy New Orleans Power. • Entergy New Orleans will contribute the membership interests in Entergy New Orleans Power to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy New Orleans Power will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC. • Entergy New Orleans will change its name to Entergy New Orleans Holdings, Inc., and Entergy New Orleans Power will then change its name to Entergy New Orleans, LLC. Upon the completion of the restructuring, Entergy New Orleans, LLC will hold substantially all of the assets, and will have assumed substantially all of the liabilities, of Entergy New Orleans. Entergy New Orleans may modify or supplement the steps to be taken to effectuate the restructuring. 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 petitioned the Texas Supreme Court to hear its appeal of the Third Court’s ruling. That petition is pending. Other Filings In September 2015, Entergy Texas filed for a transmission cost recovery factor (TCRF) 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 April 2016 the PUCT voted to allow Entergy Texas’s TCRF rates to become effective as of April 14, 2016 when those rates are finally approved, but did not otherwise address the proposal for decision. 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. In June 2016 the PUCT indicated that it would take up in a future rulemaking project the issue of whether a load growth adjustment should apply to a TCRF. In July 2016 the PUCT issued an order generally accepting the proposal for decision but declining to adjust the TCRF baseline in two instances as recommended by the ALJ, which results in a total annual allowance of approximately $10.5 million . The PUCT also ordered its staff and Entergy Texas to track all spare autotransformer transfers going forward so that it could address the appropriate accounting treatment and prudence of such transfers in Entergy Texas’s next base rate case. System Agreement Cost Equalization Proceedings Rough Production Cost Equalization Rates Consolidated 2011, 2012, 2013, and 2014 Rate Filing Proceedings As discussed in the Form 10-K, in December 2014 the FERC consolidated the 2011, 2012, 2013, and 2014 rate filings for settlement and hearing procedures. In May 2015, Entergy filed direct testimony in the consolidated rate filings and the LPSC filed direct testimony concerning its complaint proceeding that is consolidated with the rate filings, challenging certain components of the pending bandwidth calculations for prior years. In July 2015 the parties filed direct and answering testimony. In August and September 2015 the parties filed additional rounds of testimony in the consolidated hearing for the 2011, 2012, 2013, and 2014 rate filings. In October 2015 the LPSC withdrew its testimony challenging the accounting for joint account sales of energy. The hearings occurred in November 2015, and an initial decision from the ALJ was issued in July 2016. In the initial decision, the ALJ generally agreed with Entergy’s bandwidth calculations with one exception on the accounting related to the Waterford 3 sale/leaseback. Briefs are due in August and September 2016. 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. The settlement is pending at the FERC. 2016 Rate Filing Based on Calendar Year 2015 Production Costs In May 2016, Entergy filed with the FERC the 2016 rates in accordance with the FERC’s orders in the System Agreement proceeding. The filing showed that no payments and receipts were required in 2016 to implement the FERC’s remedy based on calendar year 2015 production costs. The LPSC and City Council intervened in the proceeding. 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. In May 2016 the LPSC filed a request for rehearing of the FERC’s April 2016 order. 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. In May 2016 a procedural schedule was established with a hearing in May
Entergy Mississippi [Member]
Public Utilities Disclosure [Text Block]	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2016, Entergy Arkansas filed its annual redetermination of the production cost allocation rider, which reflected recovery of the production cost allocation rider true-up adjustment of the 2014 and 2015 unrecovered retail balance in the amount of $1.9 million . Additionally, the redetermined rates reflect the recovery of a $1.9 million System Agreement bandwidth remedy payment resulting from a compliance filing pursuant to the FERC’s December 2015 order related to test year 2009 production costs. The rates for the 2016 production cost allocation rider update became effective with the first billing cycle of July 2016, and rates will be effective through June 2017. Entergy Louisiana In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. The LPSC staff issued its audit report in January 2013. The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million , plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates. The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing. Two parties intervened in the proceeding. A procedural schedule was established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC staff report and any issues raised by intervenors. One intervenor sought further proceedings regarding certain issues it raised in its comments on the LPSC staff report. Entergy Louisiana filed responses to both the LPSC staff report and the issues raised by the intervenor. After conducting additional discovery, in April 2016 the LPSC staff consultant issued its supplemental audit report, which concluded that Entergy Louisiana was not imprudent on the issues raised by the intervenor. A procedural schedule has been established for this proceeding, including an evidentiary hearing in November 2016. In December 2011 the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through 2009. In March 2016 the LPSC staff consultant issued its audit report. In its report, the LPSC staff consultant recommended that Entergy Louisiana refund approximately $8.6 million , plus interest, to customers and realign the recovery of approximately $12.7 million from Entergy Gulf States Louisiana’s fuel adjustment clause to base rates. Entergy Louisiana has recorded a provision for the estimated outcome of this proceeding. A procedural schedule has been established for this proceeding, including a hearing in December 2016. In June 2016 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. In recognition of the business combination that occurred in 2015, the audit notice was issued to Entergy Louisiana and will also include a review of charges to legacy Entergy Gulf States Louisiana customers prior to the business combination. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment and purchased gas adjustment mechanisms for the period from 2012 through 2015. Discovery has not commenced. Entergy Mississippi Entergy Mississippi had a deferred fuel over-recovery balance of $58.3 million as of May 31, 2015, along with an under-recovery balance of $12.3 million under the power management rider. Pursuant to those tariffs, in July 2015, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider to flow through to customers the approximately $46 million net over-recovery over a six-month period. In August 2015 the MPSC approved the interim adjustments effective with September 2015 bills. In November 2015, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included a projected over-recovery balance of $48 million projected through January 31, 2016. In January 2016 the MPSC approved the redetermined annual factor effective February 1, 2016. The MPSC further ordered, however, that due to the significant change in natural gas price forecasts since Entergy Mississippi’s filing in November 2015, Entergy Mississippi shall file a revised fuel factor with the MPSC no later than February 1, 2016. Pursuant to that order, Entergy Mississippi submitted a revised fuel factor. Additionally, because Entergy Mississippi’s projected over-recovery balance for the period ending January 31, 2017 was $68 million , in February 2016, Entergy Mississippi filed for another interim adjustment to the energy cost factor effective April 2016 to flow through to customers the projected over-recovery balance over a six-month period. That interim adjustment was approved by the MPSC in February 2016 effective for April 2016 bills. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in the open proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional $10.9 million in bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. Both appeals are pending, but the appeals do not stay the PUCT’s decision. The federal appeal is scheduled to be heard in December 2016. In April 2016, Entergy Texas filed with the PUCT an application to refund to customers approximately $56.2 million . The refund resulted from (i) $41.8 million of fuel cost recovery over-collections through February 2016, (ii) the $10.9 million in bandwidth remedy payments, discussed above, that Entergy Texas received related to calendar year 2006 production costs, and (iii) $3.5 million in bandwidth remedy payments that Entergy Texas received related to 2006-2008 production costs. In June 2016, Entergy Texas filed an unopposed settlement agreement that added additional over-recovered fuel costs for the months of March and April 2016. The settlement resulted in a $68 million refund. The ALJ approved the refund on an interim basis to be made to most customers over a four-month period beginning with the first billing cycle of July 2016. In July 2016 the PUCT issued an order approving the interim refund. In July 2016, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period April 1, 2013 through March 31, 2016. Under a recent PUCT rule change, a fuel reconciliation is required to be filed at least once every three years and outside of a base rate case filing. During the reconciliation period, Entergy Texas incurred approximately $1.77 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimates an over-recovery balance of approximately $19.3 million , including interest, which Entergy Texas is requesting authority to carry over as the beginning balance for the subsequent reconciliation period beginning Apri1 2016. Entergy Texas also notes, however, that the $19.3 million over collection is currently being refunded to customers as a portion of the interim fuel refund beginning with the first billing cycle of July 2016, discussed above. Entergy Texas also is requesting a prudence finding for each of the fuel-related contracts and arrangements entered into or modified during the reconciliation period that have not be reviewed by the PUCT in a prior proceeding. The PUCT has one year to issue a final order in this proceeding. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC 2015 Rate Case In April 2015, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. The filing notified the APSC of Entergy Arkansas’s intent to implement a formula rate review mechanism pursuant to Arkansas legislation passed in 2015, and requested a retail rate increase of $268.4 million , with a net increase in revenue of $167 million. The filing requested a 10.2% return on common equity. In September 2015 the APSC staff and intervenors filed direct testimony, with the APSC staff recommending a revenue requirement of $217.9 million and a 9.65% return on common equity. In December 2015, Entergy Arkansas, the APSC staff, and certain of the intervenors in the rate case filed with the APSC a joint motion for approval of a settlement of the case that proposed a retail rate increase of approximately $225 million with a net increase in revenue of approximately $133 million ; an authorized return on common equity of 9.75% ; and a formula rate plan tariff that provides a +/- 50 basis point band around the 9.75% allowed return on common equity. A significant portion of the rate increase is related to Entergy Arkansas’s acquisition in March 2016 of Union Power Station Power Block 2 for a base purchase price of $237 million , subject to closing adjustments. The settlement agreement also provided for amortization over a 10-year period of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance. A settlement hearing was held in January 2016. In February 2016 the APSC approved the settlement with one exception that would reduce the retail rate increase proposed in the settlement by $5 million . The settling parties agreed to the APSC modifications in February 2016. The new rates were effective February 24, 2016 and began billing with the first billing cycle of April 2016. In March 2016, Entergy Arkansas made a compliance filing regarding the new rates that included an interim base rate adjustment surcharge, effective with the first billing cycle of April 2016, to recover the incremental revenue requirement for the period February 24, 2016 through March 31, 2016. The interim base rate adjustment surcharge will recover a total of $21.1 million over the nine-month period from April 2016 through December 2016. 2016 Formula Rate Plan Filing In July 2016, Entergy Arkansas filed with the APSC its 2016 Entergy Arkansas formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2017 test year to be below the formula rate plan bandwidth. The filing requests a $68 million rate increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . Entergy Arkansas requested an order approving its proposed formula rate plan adjustment by December 9, 2016. If a final order is not issued by this date, the proposed formula rate plan adjustment will become effective December 30, 2016, subject to refund. Filings with the LPSC Retail Rates - Electric 2015 Formula Rate Plan Filing In May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. The evaluation report reflects an earned return on common equity of 9.07% . As such, no adjustment to base formula rate plan revenue is required. The following other adjustments, however, are required under the formula rate plan: an increase in the legacy Entergy Louisiana additional capacity mechanism of $14.2 million ; a separate increase in legacy Entergy Louisiana revenue of $10 million primarily to reflect the effects of the termination of the System Agreement; an increase in the legacy Entergy Gulf States Louisiana additional capacity mechanism of $0.5 million ; a decrease in legacy Entergy Gulf States Louisiana revenue of $58.7 million primarily to reflect the effects of the termination of the System Agreement; and an increase of $11 million to the MISO cost recovery mechanism. Rates are scheduled to be implemented with the first billing cycle of September 2016, subject to refund. 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 had questioned the warranty coverage for one element of the project. In March 2016, Entergy Louisiana and the LPSC staff filed a joint motion to suspend the procedural schedule pending the filing of an uncontested joint stipulated settlement. Union Power Station As discussed in the Form 10-K, in October 2015 the LPSC approved a settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station. In March 2016, Entergy Louisiana acquired Power Blocks 3 and 4 of Union Power Station for an aggregate purchase price of approximately $474 million and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. As a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. Parties have requested further proceedings on the prudence of Entergy Louisiana’s decision to deactivate Willow Glen 2 and 4. This matter is pending before an ALJ, and a hearing has been scheduled in March 2017 to determine, under applicable law, whether Willow Glen 2 and 4 units should be returned to service. Retail Rates - Gas In January 2016, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2015. The filing showed an earned return on common equity of 10.22% , which is within the authorized bandwidth, therefore requiring no change in rates. In March 2016 the LPSC staff issued its report stating that the 2015 gas rate stabilization plan filing is in compliance with the exception of several issues that require additional information, explanation, or clarification for which the LPSC staff has reserved the right to further review. In July 2016 the parties to the proceeding filed an unopposed joint report and motion for entry of order accepting report that indicates no outstanding issues remain in the filing. Absent approval of an extension by the LPSC, test year 2015 is the final year under the current gas rate stabilization plan. In February 2016, however, Entergy Louisiana filed a motion requesting to extend the term of the gas rate stabilization plan for an additional three-year term. A procedural schedule has been established, including a hearing in November 2016. Filings with the MPSC In March 2016, Entergy Mississippi submitted its formula rate plan 2016 test year filing showing Entergy Mississippi’s projected earned return for the 2016 calendar year to be below the formula rate plan bandwidth. The filing showed a $32.6 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 9.96% , within the formula rate plan bandwidth. In June 2016 the MPSC approved Entergy Mississippi’s joint stipulation with the Mississippi Public Utilities Staff. The joint stipulation provided for a total revenue increase of $23.7 million . The revenue increase includes a $19.4 million increase through the formula rate plan, resulting in a return on common equity point of adjustment of 10.07% . The revenue increase also includes $4.3 million in incremental ad valorem tax expenses to be collected through an updated ad valorem tax adjustment rider. The revenue increase and ad valorem tax adjustment rider were effective with the July 2016 bills. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the terms of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6, the revenue requirement associated with the purchase of Power Block 1 of the Union Power Station, and a credit to customers of $400 thousand monthly beginning June 2016 in recognition of the decrease in other operation and maintenance expenses that would result with the deactivation of Michoud Units 2 and 3. In March 2016, Entergy New Orleans purchased Power Block 1 of the Union Power Station for approximately $237 million and initiated recovery of these costs with March 2016 bills. In July 2016, Entergy New Orleans and the City Council Utility Committee agreed to a temporary increase in the credit to customers to a total of $1.4 million monthly for August 2016 through December 2016. Internal Restructuring In July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring which would result in the transfer of substantially all of the assets and operations of Entergy New Orleans to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval of the City Council and the FERC. If the application is approved by the City Council in 2016, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2016 and 2017. The filing with the FERC has not yet been made, but if the restructuring is approved by the FERC by December 31, 2018, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2018, 2019, and 2020. If City Council and FERC approvals are obtained, Entergy New Orleans expects the restructuring will be consummated by December 31, 2017. It is currently contemplated that Entergy New Orleans would undertake a multi-step restructuring, which would include the following: • Entergy New Orleans would redeem its outstanding preferred stock at a price of approximately $21 million , which includes an expected call premium of approximately $819,000 , plus any accumulated and unpaid dividends. • Entergy New Orleans would convert from a Louisiana corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy New Orleans will allocate substantially all of its assets to a new subsidiary, Entergy New Orleans Power, LLC, a Texas limited liability company (Entergy New Orleans Power), and Entergy New Orleans Power will assume substantially all of the liabilities of Entergy New Orleans, in a transaction regarded as a merger under the TXBOC. Entergy New Orleans will remain in existence and hold the membership interests in Entergy New Orleans Power. • Entergy New Orleans will contribute the membership interests in Entergy New Orleans Power to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy New Orleans Power will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC. • Entergy New Orleans will change its name to Entergy New Orleans Holdings, Inc., and Entergy New Orleans Power will then change its name to Entergy New Orleans, LLC. Upon the completion of the restructuring, Entergy New Orleans, LLC will hold substantially all of the assets, and will have assumed substantially all of the liabilities, of Entergy New Orleans. Entergy New Orleans may modify or supplement the steps to be taken to effectuate the restructuring. 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 petitioned the Texas Supreme Court to hear its appeal of the Third Court’s ruling. That petition is pending. Other Filings In September 2015, Entergy Texas filed for a transmission cost recovery factor (TCRF) 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 April 2016 the PUCT voted to allow Entergy Texas’s TCRF rates to become effective as of April 14, 2016 when those rates are finally approved, but did not otherwise address the proposal for decision. 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. In June 2016 the PUCT indicated that it would take up in a future rulemaking project the issue of whether a load growth adjustment should apply to a TCRF. In July 2016 the PUCT issued an order generally accepting the proposal for decision but declining to adjust the TCRF baseline in two instances as recommended by the ALJ, which results in a total annual allowance of approximately $10.5 million . The PUCT also ordered its staff and Entergy Texas to track all spare autotransformer transfers going forward so that it could address the appropriate accounting treatment and prudence of such transfers in Entergy Texas’s next base rate case. System Agreement Cost Equalization Proceedings Rough Production Cost Equalization Rates Consolidated 2011, 2012, 2013, and 2014 Rate Filing Proceedings As discussed in the Form 10-K, in December 2014 the FERC consolidated the 2011, 2012, 2013, and 2014 rate filings for settlement and hearing procedures. In May 2015, Entergy filed direct testimony in the consolidated rate filings and the LPSC filed direct testimony concerning its complaint proceeding that is consolidated with the rate filings, challenging certain components of the pending bandwidth calculations for prior years. In July 2015 the parties filed direct and answering testimony. In August and September 2015 the parties filed additional rounds of testimony in the consolidated hearing for the 2011, 2012, 2013, and 2014 rate filings. In October 2015 the LPSC withdrew its testimony challenging the accounting for joint account sales of energy. The hearings occurred in November 2015, and an initial decision from the ALJ was issued in July 2016. In the initial decision, the ALJ generally agreed with Entergy’s bandwidth calculations with one exception on the accounting related to the Waterford 3 sale/leaseback. Briefs are due in August and September 2016. 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. The settlement is pending at the FERC. 2016 Rate Filing Based on Calendar Year 2015 Production Costs In May 2016, Entergy filed with the FERC the 2016 rates in accordance with the FERC’s orders in the System Agreement proceeding. The filing showed that no payments and receipts were required in 2016 to implement the FERC’s remedy based on calendar year 2015 production costs. The LPSC and City Council intervened in the proceeding. 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. In May 2016 the LPSC filed a request for rehearing of the FERC’s April 2016 order. 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. In May 2016 a procedural schedule was established with a hearing in May
Entergy New Orleans [Member]
Public Utilities Disclosure [Text Block]	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2016, Entergy Arkansas filed its annual redetermination of the production cost allocation rider, which reflected recovery of the production cost allocation rider true-up adjustment of the 2014 and 2015 unrecovered retail balance in the amount of $1.9 million . Additionally, the redetermined rates reflect the recovery of a $1.9 million System Agreement bandwidth remedy payment resulting from a compliance filing pursuant to the FERC’s December 2015 order related to test year 2009 production costs. The rates for the 2016 production cost allocation rider update became effective with the first billing cycle of July 2016, and rates will be effective through June 2017. Entergy Louisiana In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. The LPSC staff issued its audit report in January 2013. The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million , plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates. The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing. Two parties intervened in the proceeding. A procedural schedule was established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC staff report and any issues raised by intervenors. One intervenor sought further proceedings regarding certain issues it raised in its comments on the LPSC staff report. Entergy Louisiana filed responses to both the LPSC staff report and the issues raised by the intervenor. After conducting additional discovery, in April 2016 the LPSC staff consultant issued its supplemental audit report, which concluded that Entergy Louisiana was not imprudent on the issues raised by the intervenor. A procedural schedule has been established for this proceeding, including an evidentiary hearing in November 2016. In December 2011 the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through 2009. In March 2016 the LPSC staff consultant issued its audit report. In its report, the LPSC staff consultant recommended that Entergy Louisiana refund approximately $8.6 million , plus interest, to customers and realign the recovery of approximately $12.7 million from Entergy Gulf States Louisiana’s fuel adjustment clause to base rates. Entergy Louisiana has recorded a provision for the estimated outcome of this proceeding. A procedural schedule has been established for this proceeding, including a hearing in December 2016. In June 2016 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. In recognition of the business combination that occurred in 2015, the audit notice was issued to Entergy Louisiana and will also include a review of charges to legacy Entergy Gulf States Louisiana customers prior to the business combination. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment and purchased gas adjustment mechanisms for the period from 2012 through 2015. Discovery has not commenced. Entergy Mississippi Entergy Mississippi had a deferred fuel over-recovery balance of $58.3 million as of May 31, 2015, along with an under-recovery balance of $12.3 million under the power management rider. Pursuant to those tariffs, in July 2015, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider to flow through to customers the approximately $46 million net over-recovery over a six-month period. In August 2015 the MPSC approved the interim adjustments effective with September 2015 bills. In November 2015, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included a projected over-recovery balance of $48 million projected through January 31, 2016. In January 2016 the MPSC approved the redetermined annual factor effective February 1, 2016. The MPSC further ordered, however, that due to the significant change in natural gas price forecasts since Entergy Mississippi’s filing in November 2015, Entergy Mississippi shall file a revised fuel factor with the MPSC no later than February 1, 2016. Pursuant to that order, Entergy Mississippi submitted a revised fuel factor. Additionally, because Entergy Mississippi’s projected over-recovery balance for the period ending January 31, 2017 was $68 million , in February 2016, Entergy Mississippi filed for another interim adjustment to the energy cost factor effective April 2016 to flow through to customers the projected over-recovery balance over a six-month period. That interim adjustment was approved by the MPSC in February 2016 effective for April 2016 bills. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in the open proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional $10.9 million in bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. Both appeals are pending, but the appeals do not stay the PUCT’s decision. The federal appeal is scheduled to be heard in December 2016. In April 2016, Entergy Texas filed with the PUCT an application to refund to customers approximately $56.2 million . The refund resulted from (i) $41.8 million of fuel cost recovery over-collections through February 2016, (ii) the $10.9 million in bandwidth remedy payments, discussed above, that Entergy Texas received related to calendar year 2006 production costs, and (iii) $3.5 million in bandwidth remedy payments that Entergy Texas received related to 2006-2008 production costs. In June 2016, Entergy Texas filed an unopposed settlement agreement that added additional over-recovered fuel costs for the months of March and April 2016. The settlement resulted in a $68 million refund. The ALJ approved the refund on an interim basis to be made to most customers over a four-month period beginning with the first billing cycle of July 2016. In July 2016 the PUCT issued an order approving the interim refund. In July 2016, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period April 1, 2013 through March 31, 2016. Under a recent PUCT rule change, a fuel reconciliation is required to be filed at least once every three years and outside of a base rate case filing. During the reconciliation period, Entergy Texas incurred approximately $1.77 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimates an over-recovery balance of approximately $19.3 million , including interest, which Entergy Texas is requesting authority to carry over as the beginning balance for the subsequent reconciliation period beginning Apri1 2016. Entergy Texas also notes, however, that the $19.3 million over collection is currently being refunded to customers as a portion of the interim fuel refund beginning with the first billing cycle of July 2016, discussed above. Entergy Texas also is requesting a prudence finding for each of the fuel-related contracts and arrangements entered into or modified during the reconciliation period that have not be reviewed by the PUCT in a prior proceeding. The PUCT has one year to issue a final order in this proceeding. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC 2015 Rate Case In April 2015, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. The filing notified the APSC of Entergy Arkansas’s intent to implement a formula rate review mechanism pursuant to Arkansas legislation passed in 2015, and requested a retail rate increase of $268.4 million , with a net increase in revenue of $167 million. The filing requested a 10.2% return on common equity. In September 2015 the APSC staff and intervenors filed direct testimony, with the APSC staff recommending a revenue requirement of $217.9 million and a 9.65% return on common equity. In December 2015, Entergy Arkansas, the APSC staff, and certain of the intervenors in the rate case filed with the APSC a joint motion for approval of a settlement of the case that proposed a retail rate increase of approximately $225 million with a net increase in revenue of approximately $133 million ; an authorized return on common equity of 9.75% ; and a formula rate plan tariff that provides a +/- 50 basis point band around the 9.75% allowed return on common equity. A significant portion of the rate increase is related to Entergy Arkansas’s acquisition in March 2016 of Union Power Station Power Block 2 for a base purchase price of $237 million , subject to closing adjustments. The settlement agreement also provided for amortization over a 10-year period of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance. A settlement hearing was held in January 2016. In February 2016 the APSC approved the settlement with one exception that would reduce the retail rate increase proposed in the settlement by $5 million . The settling parties agreed to the APSC modifications in February 2016. The new rates were effective February 24, 2016 and began billing with the first billing cycle of April 2016. In March 2016, Entergy Arkansas made a compliance filing regarding the new rates that included an interim base rate adjustment surcharge, effective with the first billing cycle of April 2016, to recover the incremental revenue requirement for the period February 24, 2016 through March 31, 2016. The interim base rate adjustment surcharge will recover a total of $21.1 million over the nine-month period from April 2016 through December 2016. 2016 Formula Rate Plan Filing In July 2016, Entergy Arkansas filed with the APSC its 2016 Entergy Arkansas formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2017 test year to be below the formula rate plan bandwidth. The filing requests a $68 million rate increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . Entergy Arkansas requested an order approving its proposed formula rate plan adjustment by December 9, 2016. If a final order is not issued by this date, the proposed formula rate plan adjustment will become effective December 30, 2016, subject to refund. Filings with the LPSC Retail Rates - Electric 2015 Formula Rate Plan Filing In May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. The evaluation report reflects an earned return on common equity of 9.07% . As such, no adjustment to base formula rate plan revenue is required. The following other adjustments, however, are required under the formula rate plan: an increase in the legacy Entergy Louisiana additional capacity mechanism of $14.2 million ; a separate increase in legacy Entergy Louisiana revenue of $10 million primarily to reflect the effects of the termination of the System Agreement; an increase in the legacy Entergy Gulf States Louisiana additional capacity mechanism of $0.5 million ; a decrease in legacy Entergy Gulf States Louisiana revenue of $58.7 million primarily to reflect the effects of the termination of the System Agreement; and an increase of $11 million to the MISO cost recovery mechanism. Rates are scheduled to be implemented with the first billing cycle of September 2016, subject to refund. 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 had questioned the warranty coverage for one element of the project. In March 2016, Entergy Louisiana and the LPSC staff filed a joint motion to suspend the procedural schedule pending the filing of an uncontested joint stipulated settlement. Union Power Station As discussed in the Form 10-K, in October 2015 the LPSC approved a settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station. In March 2016, Entergy Louisiana acquired Power Blocks 3 and 4 of Union Power Station for an aggregate purchase price of approximately $474 million and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. As a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. Parties have requested further proceedings on the prudence of Entergy Louisiana’s decision to deactivate Willow Glen 2 and 4. This matter is pending before an ALJ, and a hearing has been scheduled in March 2017 to determine, under applicable law, whether Willow Glen 2 and 4 units should be returned to service. Retail Rates - Gas In January 2016, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2015. The filing showed an earned return on common equity of 10.22% , which is within the authorized bandwidth, therefore requiring no change in rates. In March 2016 the LPSC staff issued its report stating that the 2015 gas rate stabilization plan filing is in compliance with the exception of several issues that require additional information, explanation, or clarification for which the LPSC staff has reserved the right to further review. In July 2016 the parties to the proceeding filed an unopposed joint report and motion for entry of order accepting report that indicates no outstanding issues remain in the filing. Absent approval of an extension by the LPSC, test year 2015 is the final year under the current gas rate stabilization plan. In February 2016, however, Entergy Louisiana filed a motion requesting to extend the term of the gas rate stabilization plan for an additional three-year term. A procedural schedule has been established, including a hearing in November 2016. Filings with the MPSC In March 2016, Entergy Mississippi submitted its formula rate plan 2016 test year filing showing Entergy Mississippi’s projected earned return for the 2016 calendar year to be below the formula rate plan bandwidth. The filing showed a $32.6 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 9.96% , within the formula rate plan bandwidth. In June 2016 the MPSC approved Entergy Mississippi’s joint stipulation with the Mississippi Public Utilities Staff. The joint stipulation provided for a total revenue increase of $23.7 million . The revenue increase includes a $19.4 million increase through the formula rate plan, resulting in a return on common equity point of adjustment of 10.07% . The revenue increase also includes $4.3 million in incremental ad valorem tax expenses to be collected through an updated ad valorem tax adjustment rider. The revenue increase and ad valorem tax adjustment rider were effective with the July 2016 bills. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the terms of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6, the revenue requirement associated with the purchase of Power Block 1 of the Union Power Station, and a credit to customers of $400 thousand monthly beginning June 2016 in recognition of the decrease in other operation and maintenance expenses that would result with the deactivation of Michoud Units 2 and 3. In March 2016, Entergy New Orleans purchased Power Block 1 of the Union Power Station for approximately $237 million and initiated recovery of these costs with March 2016 bills. In July 2016, Entergy New Orleans and the City Council Utility Committee agreed to a temporary increase in the credit to customers to a total of $1.4 million monthly for August 2016 through December 2016. Internal Restructuring In July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring which would result in the transfer of substantially all of the assets and operations of Entergy New Orleans to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval of the City Council and the FERC. If the application is approved by the City Council in 2016, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2016 and 2017. The filing with the FERC has not yet been made, but if the restructuring is approved by the FERC by December 31, 2018, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2018, 2019, and 2020. If City Council and FERC approvals are obtained, Entergy New Orleans expects the restructuring will be consummated by December 31, 2017. It is currently contemplated that Entergy New Orleans would undertake a multi-step restructuring, which would include the following: • Entergy New Orleans would redeem its outstanding preferred stock at a price of approximately $21 million , which includes an expected call premium of approximately $819,000 , plus any accumulated and unpaid dividends. • Entergy New Orleans would convert from a Louisiana corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy New Orleans will allocate substantially all of its assets to a new subsidiary, Entergy New Orleans Power, LLC, a Texas limited liability company (Entergy New Orleans Power), and Entergy New Orleans Power will assume substantially all of the liabilities of Entergy New Orleans, in a transaction regarded as a merger under the TXBOC. Entergy New Orleans will remain in existence and hold the membership interests in Entergy New Orleans Power. • Entergy New Orleans will contribute the membership interests in Entergy New Orleans Power to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy New Orleans Power will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC. • Entergy New Orleans will change its name to Entergy New Orleans Holdings, Inc., and Entergy New Orleans Power will then change its name to Entergy New Orleans, LLC. Upon the completion of the restructuring, Entergy New Orleans, LLC will hold substantially all of the assets, and will have assumed substantially all of the liabilities, of Entergy New Orleans. Entergy New Orleans may modify or supplement the steps to be taken to effectuate the restructuring. 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 petitioned the Texas Supreme Court to hear its appeal of the Third Court’s ruling. That petition is pending. Other Filings In September 2015, Entergy Texas filed for a transmission cost recovery factor (TCRF) 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 April 2016 the PUCT voted to allow Entergy Texas’s TCRF rates to become effective as of April 14, 2016 when those rates are finally approved, but did not otherwise address the proposal for decision. 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. In June 2016 the PUCT indicated that it would take up in a future rulemaking project the issue of whether a load growth adjustment should apply to a TCRF. In July 2016 the PUCT issued an order generally accepting the proposal for decision but declining to adjust the TCRF baseline in two instances as recommended by the ALJ, which results in a total annual allowance of approximately $10.5 million . The PUCT also ordered its staff and Entergy Texas to track all spare autotransformer transfers going forward so that it could address the appropriate accounting treatment and prudence of such transfers in Entergy Texas’s next base rate case. System Agreement Cost Equalization Proceedings Rough Production Cost Equalization Rates Consolidated 2011, 2012, 2013, and 2014 Rate Filing Proceedings As discussed in the Form 10-K, in December 2014 the FERC consolidated the 2011, 2012, 2013, and 2014 rate filings for settlement and hearing procedures. In May 2015, Entergy filed direct testimony in the consolidated rate filings and the LPSC filed direct testimony concerning its complaint proceeding that is consolidated with the rate filings, challenging certain components of the pending bandwidth calculations for prior years. In July 2015 the parties filed direct and answering testimony. In August and September 2015 the parties filed additional rounds of testimony in the consolidated hearing for the 2011, 2012, 2013, and 2014 rate filings. In October 2015 the LPSC withdrew its testimony challenging the accounting for joint account sales of energy. The hearings occurred in November 2015, and an initial decision from the ALJ was issued in July 2016. In the initial decision, the ALJ generally agreed with Entergy’s bandwidth calculations with one exception on the accounting related to the Waterford 3 sale/leaseback. Briefs are due in August and September 2016. 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. The settlement is pending at the FERC. 2016 Rate Filing Based on Calendar Year 2015 Production Costs In May 2016, Entergy filed with the FERC the 2016 rates in accordance with the FERC’s orders in the System Agreement proceeding. The filing showed that no payments and receipts were required in 2016 to implement the FERC’s remedy based on calendar year 2015 production costs. The LPSC and City Council intervened in the proceeding. 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. In May 2016 the LPSC filed a request for rehearing of the FERC’s April 2016 order. 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. In May 2016 a procedural schedule was established with a hearing in May
Entergy Texas [Member]
Public Utilities Disclosure [Text Block]	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2016, Entergy Arkansas filed its annual redetermination of the production cost allocation rider, which reflected recovery of the production cost allocation rider true-up adjustment of the 2014 and 2015 unrecovered retail balance in the amount of $1.9 million . Additionally, the redetermined rates reflect the recovery of a $1.9 million System Agreement bandwidth remedy payment resulting from a compliance filing pursuant to the FERC’s December 2015 order related to test year 2009 production costs. The rates for the 2016 production cost allocation rider update became effective with the first billing cycle of July 2016, and rates will be effective through June 2017. Entergy Louisiana In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. The LPSC staff issued its audit report in January 2013. The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million , plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates. The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing. Two parties intervened in the proceeding. A procedural schedule was established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC staff report and any issues raised by intervenors. One intervenor sought further proceedings regarding certain issues it raised in its comments on the LPSC staff report. Entergy Louisiana filed responses to both the LPSC staff report and the issues raised by the intervenor. After conducting additional discovery, in April 2016 the LPSC staff consultant issued its supplemental audit report, which concluded that Entergy Louisiana was not imprudent on the issues raised by the intervenor. A procedural schedule has been established for this proceeding, including an evidentiary hearing in November 2016. In December 2011 the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through 2009. In March 2016 the LPSC staff consultant issued its audit report. In its report, the LPSC staff consultant recommended that Entergy Louisiana refund approximately $8.6 million , plus interest, to customers and realign the recovery of approximately $12.7 million from Entergy Gulf States Louisiana’s fuel adjustment clause to base rates. Entergy Louisiana has recorded a provision for the estimated outcome of this proceeding. A procedural schedule has been established for this proceeding, including a hearing in December 2016. In June 2016 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. In recognition of the business combination that occurred in 2015, the audit notice was issued to Entergy Louisiana and will also include a review of charges to legacy Entergy Gulf States Louisiana customers prior to the business combination. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment and purchased gas adjustment mechanisms for the period from 2012 through 2015. Discovery has not commenced. Entergy Mississippi Entergy Mississippi had a deferred fuel over-recovery balance of $58.3 million as of May 31, 2015, along with an under-recovery balance of $12.3 million under the power management rider. Pursuant to those tariffs, in July 2015, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider to flow through to customers the approximately $46 million net over-recovery over a six-month period. In August 2015 the MPSC approved the interim adjustments effective with September 2015 bills. In November 2015, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included a projected over-recovery balance of $48 million projected through January 31, 2016. In January 2016 the MPSC approved the redetermined annual factor effective February 1, 2016. The MPSC further ordered, however, that due to the significant change in natural gas price forecasts since Entergy Mississippi’s filing in November 2015, Entergy Mississippi shall file a revised fuel factor with the MPSC no later than February 1, 2016. Pursuant to that order, Entergy Mississippi submitted a revised fuel factor. Additionally, because Entergy Mississippi’s projected over-recovery balance for the period ending January 31, 2017 was $68 million , in February 2016, Entergy Mississippi filed for another interim adjustment to the energy cost factor effective April 2016 to flow through to customers the projected over-recovery balance over a six-month period. That interim adjustment was approved by the MPSC in February 2016 effective for April 2016 bills. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in the open proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional $10.9 million in bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. Both appeals are pending, but the appeals do not stay the PUCT’s decision. The federal appeal is scheduled to be heard in December 2016. In April 2016, Entergy Texas filed with the PUCT an application to refund to customers approximately $56.2 million . The refund resulted from (i) $41.8 million of fuel cost recovery over-collections through February 2016, (ii) the $10.9 million in bandwidth remedy payments, discussed above, that Entergy Texas received related to calendar year 2006 production costs, and (iii) $3.5 million in bandwidth remedy payments that Entergy Texas received related to 2006-2008 production costs. In June 2016, Entergy Texas filed an unopposed settlement agreement that added additional over-recovered fuel costs for the months of March and April 2016. The settlement resulted in a $68 million refund. The ALJ approved the refund on an interim basis to be made to most customers over a four-month period beginning with the first billing cycle of July 2016. In July 2016 the PUCT issued an order approving the interim refund. In July 2016, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period April 1, 2013 through March 31, 2016. Under a recent PUCT rule change, a fuel reconciliation is required to be filed at least once every three years and outside of a base rate case filing. During the reconciliation period, Entergy Texas incurred approximately $1.77 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimates an over-recovery balance of approximately $19.3 million , including interest, which Entergy Texas is requesting authority to carry over as the beginning balance for the subsequent reconciliation period beginning Apri1 2016. Entergy Texas also notes, however, that the $19.3 million over collection is currently being refunded to customers as a portion of the interim fuel refund beginning with the first billing cycle of July 2016, discussed above. Entergy Texas also is requesting a prudence finding for each of the fuel-related contracts and arrangements entered into or modified during the reconciliation period that have not be reviewed by the PUCT in a prior proceeding. The PUCT has one year to issue a final order in this proceeding. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC 2015 Rate Case In April 2015, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. The filing notified the APSC of Entergy Arkansas’s intent to implement a formula rate review mechanism pursuant to Arkansas legislation passed in 2015, and requested a retail rate increase of $268.4 million , with a net increase in revenue of $167 million. The filing requested a 10.2% return on common equity. In September 2015 the APSC staff and intervenors filed direct testimony, with the APSC staff recommending a revenue requirement of $217.9 million and a 9.65% return on common equity. In December 2015, Entergy Arkansas, the APSC staff, and certain of the intervenors in the rate case filed with the APSC a joint motion for approval of a settlement of the case that proposed a retail rate increase of approximately $225 million with a net increase in revenue of approximately $133 million ; an authorized return on common equity of 9.75% ; and a formula rate plan tariff that provides a +/- 50 basis point band around the 9.75% allowed return on common equity. A significant portion of the rate increase is related to Entergy Arkansas’s acquisition in March 2016 of Union Power Station Power Block 2 for a base purchase price of $237 million , subject to closing adjustments. The settlement agreement also provided for amortization over a 10-year period of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance. A settlement hearing was held in January 2016. In February 2016 the APSC approved the settlement with one exception that would reduce the retail rate increase proposed in the settlement by $5 million . The settling parties agreed to the APSC modifications in February 2016. The new rates were effective February 24, 2016 and began billing with the first billing cycle of April 2016. In March 2016, Entergy Arkansas made a compliance filing regarding the new rates that included an interim base rate adjustment surcharge, effective with the first billing cycle of April 2016, to recover the incremental revenue requirement for the period February 24, 2016 through March 31, 2016. The interim base rate adjustment surcharge will recover a total of $21.1 million over the nine-month period from April 2016 through December 2016. 2016 Formula Rate Plan Filing In July 2016, Entergy Arkansas filed with the APSC its 2016 Entergy Arkansas formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2017 test year to be below the formula rate plan bandwidth. The filing requests a $68 million rate increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . Entergy Arkansas requested an order approving its proposed formula rate plan adjustment by December 9, 2016. If a final order is not issued by this date, the proposed formula rate plan adjustment will become effective December 30, 2016, subject to refund. Filings with the LPSC Retail Rates - Electric 2015 Formula Rate Plan Filing In May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. The evaluation report reflects an earned return on common equity of 9.07% . As such, no adjustment to base formula rate plan revenue is required. The following other adjustments, however, are required under the formula rate plan: an increase in the legacy Entergy Louisiana additional capacity mechanism of $14.2 million ; a separate increase in legacy Entergy Louisiana revenue of $10 million primarily to reflect the effects of the termination of the System Agreement; an increase in the legacy Entergy Gulf States Louisiana additional capacity mechanism of $0.5 million ; a decrease in legacy Entergy Gulf States Louisiana revenue of $58.7 million primarily to reflect the effects of the termination of the System Agreement; and an increase of $11 million to the MISO cost recovery mechanism. Rates are scheduled to be implemented with the first billing cycle of September 2016, subject to refund. 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 had questioned the warranty coverage for one element of the project. In March 2016, Entergy Louisiana and the LPSC staff filed a joint motion to suspend the procedural schedule pending the filing of an uncontested joint stipulated settlement. Union Power Station As discussed in the Form 10-K, in October 2015 the LPSC approved a settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station. In March 2016, Entergy Louisiana acquired Power Blocks 3 and 4 of Union Power Station for an aggregate purchase price of approximately $474 million and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. As a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. Parties have requested further proceedings on the prudence of Entergy Louisiana’s decision to deactivate Willow Glen 2 and 4. This matter is pending before an ALJ, and a hearing has been scheduled in March 2017 to determine, under applicable law, whether Willow Glen 2 and 4 units should be returned to service. Retail Rates - Gas In January 2016, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2015. The filing showed an earned return on common equity of 10.22% , which is within the authorized bandwidth, therefore requiring no change in rates. In March 2016 the LPSC staff issued its report stating that the 2015 gas rate stabilization plan filing is in compliance with the exception of several issues that require additional information, explanation, or clarification for which the LPSC staff has reserved the right to further review. In July 2016 the parties to the proceeding filed an unopposed joint report and motion for entry of order accepting report that indicates no outstanding issues remain in the filing. Absent approval of an extension by the LPSC, test year 2015 is the final year under the current gas rate stabilization plan. In February 2016, however, Entergy Louisiana filed a motion requesting to extend the term of the gas rate stabilization plan for an additional three-year term. A procedural schedule has been established, including a hearing in November 2016. Filings with the MPSC In March 2016, Entergy Mississippi submitted its formula rate plan 2016 test year filing showing Entergy Mississippi’s projected earned return for the 2016 calendar year to be below the formula rate plan bandwidth. The filing showed a $32.6 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 9.96% , within the formula rate plan bandwidth. In June 2016 the MPSC approved Entergy Mississippi’s joint stipulation with the Mississippi Public Utilities Staff. The joint stipulation provided for a total revenue increase of $23.7 million . The revenue increase includes a $19.4 million increase through the formula rate plan, resulting in a return on common equity point of adjustment of 10.07% . The revenue increase also includes $4.3 million in incremental ad valorem tax expenses to be collected through an updated ad valorem tax adjustment rider. The revenue increase and ad valorem tax adjustment rider were effective with the July 2016 bills. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the terms of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6, the revenue requirement associated with the purchase of Power Block 1 of the Union Power Station, and a credit to customers of $400 thousand monthly beginning June 2016 in recognition of the decrease in other operation and maintenance expenses that would result with the deactivation of Michoud Units 2 and 3. In March 2016, Entergy New Orleans purchased Power Block 1 of the Union Power Station for approximately $237 million and initiated recovery of these costs with March 2016 bills. In July 2016, Entergy New Orleans and the City Council Utility Committee agreed to a temporary increase in the credit to customers to a total of $1.4 million monthly for August 2016 through December 2016. Internal Restructuring In July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring which would result in the transfer of substantially all of the assets and operations of Entergy New Orleans to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval of the City Council and the FERC. If the application is approved by the City Council in 2016, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2016 and 2017. The filing with the FERC has not yet been made, but if the restructuring is approved by the FERC by December 31, 2018, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2018, 2019, and 2020. If City Council and FERC approvals are obtained, Entergy New Orleans expects the restructuring will be consummated by December 31, 2017. It is currently contemplated that Entergy New Orleans would undertake a multi-step restructuring, which would include the following: • Entergy New Orleans would redeem its outstanding preferred stock at a price of approximately $21 million , which includes an expected call premium of approximately $819,000 , plus any accumulated and unpaid dividends. • Entergy New Orleans would convert from a Louisiana corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy New Orleans will allocate substantially all of its assets to a new subsidiary, Entergy New Orleans Power, LLC, a Texas limited liability company (Entergy New Orleans Power), and Entergy New Orleans Power will assume substantially all of the liabilities of Entergy New Orleans, in a transaction regarded as a merger under the TXBOC. Entergy New Orleans will remain in existence and hold the membership interests in Entergy New Orleans Power. • Entergy New Orleans will contribute the membership interests in Entergy New Orleans Power to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy New Orleans Power will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC. • Entergy New Orleans will change its name to Entergy New Orleans Holdings, Inc., and Entergy New Orleans Power will then change its name to Entergy New Orleans, LLC. Upon the completion of the restructuring, Entergy New Orleans, LLC will hold substantially all of the assets, and will have assumed substantially all of the liabilities, of Entergy New Orleans. Entergy New Orleans may modify or supplement the steps to be taken to effectuate the restructuring. 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 petitioned the Texas Supreme Court to hear its appeal of the Third Court’s ruling. That petition is pending. Other Filings In September 2015, Entergy Texas filed for a transmission cost recovery factor (TCRF) 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 April 2016 the PUCT voted to allow Entergy Texas’s TCRF rates to become effective as of April 14, 2016 when those rates are finally approved, but did not otherwise address the proposal for decision. 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. In June 2016 the PUCT indicated that it would take up in a future rulemaking project the issue of whether a load growth adjustment should apply to a TCRF. In July 2016 the PUCT issued an order generally accepting the proposal for decision but declining to adjust the TCRF baseline in two instances as recommended by the ALJ, which results in a total annual allowance of approximately $10.5 million . The PUCT also ordered its staff and Entergy Texas to track all spare autotransformer transfers going forward so that it could address the appropriate accounting treatment and prudence of such transfers in Entergy Texas’s next base rate case. System Agreement Cost Equalization Proceedings Rough Production Cost Equalization Rates Consolidated 2011, 2012, 2013, and 2014 Rate Filing Proceedings As discussed in the Form 10-K, in December 2014 the FERC consolidated the 2011, 2012, 2013, and 2014 rate filings for settlement and hearing procedures. In May 2015, Entergy filed direct testimony in the consolidated rate filings and the LPSC filed direct testimony concerning its complaint proceeding that is consolidated with the rate filings, challenging certain components of the pending bandwidth calculations for prior years. In July 2015 the parties filed direct and answering testimony. In August and September 2015 the parties filed additional rounds of testimony in the consolidated hearing for the 2011, 2012, 2013, and 2014 rate filings. In October 2015 the LPSC withdrew its testimony challenging the accounting for joint account sales of energy. The hearings occurred in November 2015, and an initial decision from the ALJ was issued in July 2016. In the initial decision, the ALJ generally agreed with Entergy’s bandwidth calculations with one exception on the accounting related to the Waterford 3 sale/leaseback. Briefs are due in August and September 2016. 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. The settlement is pending at the FERC. 2016 Rate Filing Based on Calendar Year 2015 Production Costs In May 2016, Entergy filed with the FERC the 2016 rates in accordance with the FERC’s orders in the System Agreement proceeding. The filing showed that no payments and receipts were required in 2016 to implement the FERC’s remedy based on calendar year 2015 production costs. The LPSC and City Council intervened in the proceeding. 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. In May 2016 the LPSC filed a request for rehearing of the FERC’s April 2016 order. 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. In May 2016 a procedural schedule was established with a hearing in May
System Energy [Member]
Public Utilities Disclosure [Text Block]	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2016, Entergy Arkansas filed its annual redetermination of the production cost allocation rider, which reflected recovery of the production cost allocation rider true-up adjustment of the 2014 and 2015 unrecovered retail balance in the amount of $1.9 million . Additionally, the redetermined rates reflect the recovery of a $1.9 million System Agreement bandwidth remedy payment resulting from a compliance filing pursuant to the FERC’s December 2015 order related to test year 2009 production costs. The rates for the 2016 production cost allocation rider update became effective with the first billing cycle of July 2016, and rates will be effective through June 2017. Entergy Louisiana In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. The LPSC staff issued its audit report in January 2013. The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million , plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates. The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing. Two parties intervened in the proceeding. A procedural schedule was established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC staff report and any issues raised by intervenors. One intervenor sought further proceedings regarding certain issues it raised in its comments on the LPSC staff report. Entergy Louisiana filed responses to both the LPSC staff report and the issues raised by the intervenor. After conducting additional discovery, in April 2016 the LPSC staff consultant issued its supplemental audit report, which concluded that Entergy Louisiana was not imprudent on the issues raised by the intervenor. A procedural schedule has been established for this proceeding, including an evidentiary hearing in November 2016. In December 2011 the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through 2009. In March 2016 the LPSC staff consultant issued its audit report. In its report, the LPSC staff consultant recommended that Entergy Louisiana refund approximately $8.6 million , plus interest, to customers and realign the recovery of approximately $12.7 million from Entergy Gulf States Louisiana’s fuel adjustment clause to base rates. Entergy Louisiana has recorded a provision for the estimated outcome of this proceeding. A procedural schedule has been established for this proceeding, including a hearing in December 2016. In June 2016 the LPSC staff provided notice of an audit of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. In recognition of the business combination that occurred in 2015, the audit notice was issued to Entergy Louisiana and will also include a review of charges to legacy Entergy Gulf States Louisiana customers prior to the business combination. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s fuel adjustment and purchased gas adjustment mechanisms for the period from 2012 through 2015. Discovery has not commenced. Entergy Mississippi Entergy Mississippi had a deferred fuel over-recovery balance of $58.3 million as of May 31, 2015, along with an under-recovery balance of $12.3 million under the power management rider. Pursuant to those tariffs, in July 2015, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider to flow through to customers the approximately $46 million net over-recovery over a six-month period. In August 2015 the MPSC approved the interim adjustments effective with September 2015 bills. In November 2015, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included a projected over-recovery balance of $48 million projected through January 31, 2016. In January 2016 the MPSC approved the redetermined annual factor effective February 1, 2016. The MPSC further ordered, however, that due to the significant change in natural gas price forecasts since Entergy Mississippi’s filing in November 2015, Entergy Mississippi shall file a revised fuel factor with the MPSC no later than February 1, 2016. Pursuant to that order, Entergy Mississippi submitted a revised fuel factor. Additionally, because Entergy Mississippi’s projected over-recovery balance for the period ending January 31, 2017 was $68 million , in February 2016, Entergy Mississippi filed for another interim adjustment to the energy cost factor effective April 2016 to flow through to customers the projected over-recovery balance over a six-month period. That interim adjustment was approved by the MPSC in February 2016 effective for April 2016 bills. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in the open proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional $10.9 million in bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. Both appeals are pending, but the appeals do not stay the PUCT’s decision. The federal appeal is scheduled to be heard in December 2016. In April 2016, Entergy Texas filed with the PUCT an application to refund to customers approximately $56.2 million . The refund resulted from (i) $41.8 million of fuel cost recovery over-collections through February 2016, (ii) the $10.9 million in bandwidth remedy payments, discussed above, that Entergy Texas received related to calendar year 2006 production costs, and (iii) $3.5 million in bandwidth remedy payments that Entergy Texas received related to 2006-2008 production costs. In June 2016, Entergy Texas filed an unopposed settlement agreement that added additional over-recovered fuel costs for the months of March and April 2016. The settlement resulted in a $68 million refund. The ALJ approved the refund on an interim basis to be made to most customers over a four-month period beginning with the first billing cycle of July 2016. In July 2016 the PUCT issued an order approving the interim refund. In July 2016, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period April 1, 2013 through March 31, 2016. Under a recent PUCT rule change, a fuel reconciliation is required to be filed at least once every three years and outside of a base rate case filing. During the reconciliation period, Entergy Texas incurred approximately $1.77 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimates an over-recovery balance of approximately $19.3 million , including interest, which Entergy Texas is requesting authority to carry over as the beginning balance for the subsequent reconciliation period beginning Apri1 2016. Entergy Texas also notes, however, that the $19.3 million over collection is currently being refunded to customers as a portion of the interim fuel refund beginning with the first billing cycle of July 2016, discussed above. Entergy Texas also is requesting a prudence finding for each of the fuel-related contracts and arrangements entered into or modified during the reconciliation period that have not be reviewed by the PUCT in a prior proceeding. The PUCT has one year to issue a final order in this proceeding. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC 2015 Rate Case In April 2015, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. The filing notified the APSC of Entergy Arkansas’s intent to implement a formula rate review mechanism pursuant to Arkansas legislation passed in 2015, and requested a retail rate increase of $268.4 million , with a net increase in revenue of $167 million. The filing requested a 10.2% return on common equity. In September 2015 the APSC staff and intervenors filed direct testimony, with the APSC staff recommending a revenue requirement of $217.9 million and a 9.65% return on common equity. In December 2015, Entergy Arkansas, the APSC staff, and certain of the intervenors in the rate case filed with the APSC a joint motion for approval of a settlement of the case that proposed a retail rate increase of approximately $225 million with a net increase in revenue of approximately $133 million ; an authorized return on common equity of 9.75% ; and a formula rate plan tariff that provides a +/- 50 basis point band around the 9.75% allowed return on common equity. A significant portion of the rate increase is related to Entergy Arkansas’s acquisition in March 2016 of Union Power Station Power Block 2 for a base purchase price of $237 million , subject to closing adjustments. The settlement agreement also provided for amortization over a 10-year period of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance. A settlement hearing was held in January 2016. In February 2016 the APSC approved the settlement with one exception that would reduce the retail rate increase proposed in the settlement by $5 million . The settling parties agreed to the APSC modifications in February 2016. The new rates were effective February 24, 2016 and began billing with the first billing cycle of April 2016. In March 2016, Entergy Arkansas made a compliance filing regarding the new rates that included an interim base rate adjustment surcharge, effective with the first billing cycle of April 2016, to recover the incremental revenue requirement for the period February 24, 2016 through March 31, 2016. The interim base rate adjustment surcharge will recover a total of $21.1 million over the nine-month period from April 2016 through December 2016. 2016 Formula Rate Plan Filing In July 2016, Entergy Arkansas filed with the APSC its 2016 Entergy Arkansas formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2017 test year to be below the formula rate plan bandwidth. The filing requests a $68 million rate increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . Entergy Arkansas requested an order approving its proposed formula rate plan adjustment by December 9, 2016. If a final order is not issued by this date, the proposed formula rate plan adjustment will become effective December 30, 2016, subject to refund. Filings with the LPSC Retail Rates - Electric 2015 Formula Rate Plan Filing In May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. The evaluation report reflects an earned return on common equity of 9.07% . As such, no adjustment to base formula rate plan revenue is required. The following other adjustments, however, are required under the formula rate plan: an increase in the legacy Entergy Louisiana additional capacity mechanism of $14.2 million ; a separate increase in legacy Entergy Louisiana revenue of $10 million primarily to reflect the effects of the termination of the System Agreement; an increase in the legacy Entergy Gulf States Louisiana additional capacity mechanism of $0.5 million ; a decrease in legacy Entergy Gulf States Louisiana revenue of $58.7 million primarily to reflect the effects of the termination of the System Agreement; and an increase of $11 million to the MISO cost recovery mechanism. Rates are scheduled to be implemented with the first billing cycle of September 2016, subject to refund. 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 had questioned the warranty coverage for one element of the project. In March 2016, Entergy Louisiana and the LPSC staff filed a joint motion to suspend the procedural schedule pending the filing of an uncontested joint stipulated settlement. Union Power Station As discussed in the Form 10-K, in October 2015 the LPSC approved a settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station. In March 2016, Entergy Louisiana acquired Power Blocks 3 and 4 of Union Power Station for an aggregate purchase price of approximately $474 million and implemented rates to collect the estimated first-year revenue requirement with the first billing cycle of March 2016. As a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. Parties have requested further proceedings on the prudence of Entergy Louisiana’s decision to deactivate Willow Glen 2 and 4. This matter is pending before an ALJ, and a hearing has been scheduled in March 2017 to determine, under applicable law, whether Willow Glen 2 and 4 units should be returned to service. Retail Rates - Gas In January 2016, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2015. The filing showed an earned return on common equity of 10.22% , which is within the authorized bandwidth, therefore requiring no change in rates. In March 2016 the LPSC staff issued its report stating that the 2015 gas rate stabilization plan filing is in compliance with the exception of several issues that require additional information, explanation, or clarification for which the LPSC staff has reserved the right to further review. In July 2016 the parties to the proceeding filed an unopposed joint report and motion for entry of order accepting report that indicates no outstanding issues remain in the filing. Absent approval of an extension by the LPSC, test year 2015 is the final year under the current gas rate stabilization plan. In February 2016, however, Entergy Louisiana filed a motion requesting to extend the term of the gas rate stabilization plan for an additional three-year term. A procedural schedule has been established, including a hearing in November 2016. Filings with the MPSC In March 2016, Entergy Mississippi submitted its formula rate plan 2016 test year filing showing Entergy Mississippi’s projected earned return for the 2016 calendar year to be below the formula rate plan bandwidth. The filing showed a $32.6 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 9.96% , within the formula rate plan bandwidth. In June 2016 the MPSC approved Entergy Mississippi’s joint stipulation with the Mississippi Public Utilities Staff. The joint stipulation provided for a total revenue increase of $23.7 million . The revenue increase includes a $19.4 million increase through the formula rate plan, resulting in a return on common equity point of adjustment of 10.07% . The revenue increase also includes $4.3 million in incremental ad valorem tax expenses to be collected through an updated ad valorem tax adjustment rider. The revenue increase and ad valorem tax adjustment rider were effective with the July 2016 bills. Filings with the City Council As discussed in the Form 10-K, in November 2015 the City Council authorized expansion of the terms of the purchased power and capacity acquisition cost recovery rider to recover the non-fuel purchased power expense from Ninemile 6, the revenue requirement associated with the purchase of Power Block 1 of the Union Power Station, and a credit to customers of $400 thousand monthly beginning June 2016 in recognition of the decrease in other operation and maintenance expenses that would result with the deactivation of Michoud Units 2 and 3. In March 2016, Entergy New Orleans purchased Power Block 1 of the Union Power Station for approximately $237 million and initiated recovery of these costs with March 2016 bills. In July 2016, Entergy New Orleans and the City Council Utility Committee agreed to a temporary increase in the credit to customers to a total of $1.4 million monthly for August 2016 through December 2016. Internal Restructuring In July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring which would result in the transfer of substantially all of the assets and operations of Entergy New Orleans to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval of the City Council and the FERC. If the application is approved by the City Council in 2016, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2016 and 2017. The filing with the FERC has not yet been made, but if the restructuring is approved by the FERC by December 31, 2018, Entergy New Orleans has proposed to credit retail customers $5 million in each of the years 2018, 2019, and 2020. If City Council and FERC approvals are obtained, Entergy New Orleans expects the restructuring will be consummated by December 31, 2017. It is currently contemplated that Entergy New Orleans would undertake a multi-step restructuring, which would include the following: • Entergy New Orleans would redeem its outstanding preferred stock at a price of approximately $21 million , which includes an expected call premium of approximately $819,000 , plus any accumulated and unpaid dividends. • Entergy New Orleans would convert from a Louisiana corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy New Orleans will allocate substantially all of its assets to a new subsidiary, Entergy New Orleans Power, LLC, a Texas limited liability company (Entergy New Orleans Power), and Entergy New Orleans Power will assume substantially all of the liabilities of Entergy New Orleans, in a transaction regarded as a merger under the TXBOC. Entergy New Orleans will remain in existence and hold the membership interests in Entergy New Orleans Power. • Entergy New Orleans will contribute the membership interests in Entergy New Orleans Power to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy New Orleans Power will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC. • Entergy New Orleans will change its name to Entergy New Orleans Holdings, Inc., and Entergy New Orleans Power will then change its name to Entergy New Orleans, LLC. Upon the completion of the restructuring, Entergy New Orleans, LLC will hold substantially all of the assets, and will have assumed substantially all of the liabilities, of Entergy New Orleans. Entergy New Orleans may modify or supplement the steps to be taken to effectuate the restructuring. 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 petitioned the Texas Supreme Court to hear its appeal of the Third Court’s ruling. That petition is pending. Other Filings In September 2015, Entergy Texas filed for a transmission cost recovery factor (TCRF) 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 April 2016 the PUCT voted to allow Entergy Texas’s TCRF rates to become effective as of April 14, 2016 when those rates are finally approved, but did not otherwise address the proposal for decision. 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. In June 2016 the PUCT indicated that it would take up in a future rulemaking project the issue of whether a load growth adjustment should apply to a TCRF. In July 2016 the PUCT issued an order generally accepting the proposal for decision but declining to adjust the TCRF baseline in two instances as recommended by the ALJ, which results in a total annual allowance of approximately $10.5 million . The PUCT also ordered its staff and Entergy Texas to track all spare autotransformer transfers going forward so that it could address the appropriate accounting treatment and prudence of such transfers in Entergy Texas’s next base rate case. System Agreement Cost Equalization Proceedings Rough Production Cost Equalization Rates Consolidated 2011, 2012, 2013, and 2014 Rate Filing Proceedings As discussed in the Form 10-K, in December 2014 the FERC consolidated the 2011, 2012, 2013, and 2014 rate filings for settlement and hearing procedures. In May 2015, Entergy filed direct testimony in the consolidated rate filings and the LPSC filed direct testimony concerning its complaint proceeding that is consolidated with the rate filings, challenging certain components of the pending bandwidth calculations for prior years. In July 2015 the parties filed direct and answering testimony. In August and September 2015 the parties filed additional rounds of testimony in the consolidated hearing for the 2011, 2012, 2013, and 2014 rate filings. In October 2015 the LPSC withdrew its testimony challenging the accounting for joint account sales of energy. The hearings occurred in November 2015, and an initial decision from the ALJ was issued in July 2016. In the initial decision, the ALJ generally agreed with Entergy’s bandwidth calculations with one exception on the accounting related to the Waterford 3 sale/leaseback. Briefs are due in August and September 2016. 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. The settlement is pending at the FERC. 2016 Rate Filing Based on Calendar Year 2015 Production Costs In May 2016, Entergy filed with the FERC the 2016 rates in accordance with the FERC’s orders in the System Agreement proceeding. The filing showed that no payments and receipts were required in 2016 to implement the FERC’s remedy based on calendar year 2015 production costs. The LPSC and City Council intervened in the proceeding. 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. In May 2016 the LPSC filed a request for rehearing of the FERC’s April 2016 order. 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. In May 2016 a procedural schedule was established with a hearing in May

Equity

Equity	6 Months Ended
	Jun. 30, 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 June 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $567.3 178.8 $3.17 $148.8 179.5 $0.83 Average dilutive effect of: Stock options 0.2 — 0.2 — Other equity plans 0.5 (0.01 ) 0.4 — Diluted earnings per share $567.3 179.5 $3.16 $148.8 180.1 $0.83 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 4.1 million for the three months ended June 30, 2016 and approximately 5.1 million for the three months ended June 30, 2015 . For the Six Months Ended June 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $797.3 178.7 $4.46 $446.9 179.6 $2.49 Average dilutive effect of: Stock options 0.1 — 0.4 (0.01 ) Other equity plans 0.4 (0.01 ) 0.3 — Diluted earnings per share $797.3 179.2 $4.45 $446.9 180.3 $2.48 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 5.1 million for the six months ended June 30, 2016 and approximately 4.3 million for the six months ended June 30, 2015 . Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K. Treasury Stock During the six months ended June 30, 2016 , Entergy Corporation issued 507,144 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards. Entergy Corporation did not repurchase any of its common stock during the six months ended June 30, 2016 . Retained Earnings On July 29, 2016, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.85 per share, payable on September 1, 2016, to holders of record as of August 11, 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 June 30, 2016 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, April 1, 2016 $96,464 ($459,042 ) $390,626 $1,744 $29,792 Other comprehensive income (loss) before reclassifications (34,138 ) — 24,016 (904 ) (11,026 ) Amounts reclassified from accumulated other comprehensive income (loss) (29,903 ) 5,043 (3,061 ) — (27,921 ) Net other comprehensive income (loss) for the period (64,041 ) 5,043 20,955 (904 ) (38,947 ) Ending balance, June 30, 2016 $32,423 ($453,999 ) $411,581 $840 ($9,155 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 2015 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, April 1, 2015 $68,788 ($561,341 ) $430,698 $2,118 ($59,737 ) Other comprehensive income (loss) before reclassifications 88,796 — (25,108 ) 667 64,355 Amounts reclassified from accumulated other comprehensive income (loss) (50,100 ) 7,438 (8,772 ) — (51,434 ) Net other comprehensive income (loss) for the period 38,696 7,438 (33,880 ) 667 12,921 Ending balance, June 30, 2015 $107,484 ($553,903 ) $396,818 $2,785 ($46,816 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2016 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, January 1, 2016 $105,970 ($466,604 ) $367,557 $2,028 $8,951 Other comprehensive income (loss) before reclassifications 56,169 — 49,048 (1,188 ) 104,029 Amounts reclassified from accumulated other comprehensive income (loss) (129,716 ) 12,605 (5,024 ) — (122,135 ) Net other comprehensive income (loss) for the period (73,547 ) 12,605 44,024 (1,188 ) (18,106 ) Ending balance, June 30, 2016 $32,423 ($453,999 ) $411,581 $840 ($9,155 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2015 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, January 1, 2015 $98,118 ($569,789 ) $426,695 $2,669 ($42,307 ) Other comprehensive income (loss) before reclassifications 67,900 13 (12,450 ) 116 55,579 Amounts reclassified from accumulated other comprehensive income (loss) (58,534 ) 15,873 (17,427 ) — (60,088 ) Net other comprehensive income (loss) for the period 9,366 15,886 (29,877 ) 116 (4,509 ) Ending balance, June 30, 2015 $107,484 ($553,903 ) $396,818 $2,785 ($46,816 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended June 30, 2016: Pension and Other (In Thousands) Beginning balance April 1, 2016 ($56,675 ) Amounts reclassified from accumulated other (230 ) Net other comprehensive income (loss) for the period (230 ) Ending balance, June 30, 2016 ($56,905 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended June 30, 2015: Pension and Other (In Thousands) Beginning balance April 1, 2015 ($78,843 ) Amounts reclassified from accumulated other 412 Net other comprehensive income (loss) for the period 412 Ending balance, June 30, 2015 ($78,431 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2016: Pension and Other (In Thousands) Beginning balance, January 1, 2016 ($56,412 ) Amounts reclassified from accumulated other (493 ) Net other comprehensive income (loss) for the period (493 ) Ending balance, June 30, 2016 ($56,905 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2015: Pension and Other (In Thousands) Beginning balance, January 1, 2015 ($79,223 ) Amounts reclassified from accumulated other 792 Net other comprehensive income (loss) for the period 792 Ending balance, June 30, 2015 ($78,431 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended June 30, 2016 are as follows: Amounts reclassified from AOCI Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $45,975 Competitive business operating revenues Interest rate swaps 30 Miscellaneous - net Total realized gain (loss) on cash flow hedges 46,005 (16,102 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $29,903 Pension and other postretirement liabilities Amortization of prior-service credit $7,355 (a) Amortization of loss (15,177 ) (a) Total amortization (7,822 ) 2,779 Income taxes Total amortization (net of tax) ($5,043 ) Net unrealized investment gain (loss) Realized gain (loss) $6,000 Interest and investment income (2,939 ) Income taxes Total realized investment gain (loss) (net of tax) $3,061 Total reclassifications for the period (net of tax) $27,921 (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 June 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $77,587 Competitive business operating revenues Interest rate swaps (510 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 77,077 (26,977 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $50,100 Pension and other postretirement liabilities Amortization of prior-service credit $5,985 (a) Amortization of loss (17,588 ) (a) Total amortization (11,603 ) 4,165 Income taxes Total amortization (net of tax) ($7,438 ) Net unrealized investment gain (loss) Realized gain (loss) $17,201 Interest and investment income (8,429 ) Income taxes Total realized investment gain (loss) (net of tax) $8,772 Total reclassifications for the period (net of tax) $51,434 (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 six months ended June 30, 2016 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $199,933 Competitive business operating revenues Interest rate swaps (370 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 199,563 (69,847 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $129,716 Pension and other postretirement liabilities Amortization of prior-service credit $14,710 (a) Amortization of loss (30,352 ) (a) Total amortization (15,642 ) 3,037 Income taxes Total amortization (net of tax) ($12,605 ) Net unrealized investment gain (loss) Realized gain (loss) $9,850 Interest and investment income (4,826 ) Income taxes Total realized investment gain (loss) (net of tax) $5,024 Total reclassifications for the period (net of tax) $122,135 (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 six months ended June 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $91,109 Competitive business operating revenues Interest rate swaps (1,056 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 90,053 (31,519 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $58,534 Pension and other postretirement liabilities Amortization of prior-service credit $11,971 (a) Amortization of loss (35,176 ) (a) Total amortization (23,205 ) 7,332 Income taxes Total amortization (net of tax) ($15,873 ) Net unrealized investment gain (loss) Realized gain (loss) $34,171 Interest and investment income (16,744 ) Income taxes Total realized investment gain (loss) (net of tax) $17,427 Total reclassifications for the period (net of tax) $60,088 (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 June 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,947 (a) Amortization of loss (1,573 ) (a) Total amortization 374 (144 ) Income taxes Total amortization (net of tax) 230 Total reclassifications for the period (net of tax) $230 (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 June 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,866 (a) Amortization of loss (2,535 ) (a) Total amortization (669 ) 257 Income taxes Total amortization (net of tax) (412 ) Total reclassifications for the period (net of tax) ($412 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the six months ended June 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $3,894 (a) Amortization of loss (3,142 ) (a) Total amortization 752 (259 ) Income taxes Total amortization (net of tax) 493 Total reclassifications for the period (net of tax) $493 (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 six months ended June 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $3,733 (a) Amortization of loss (5,070 ) (a) Total amortization (1,337 ) 545 Income taxes Total amortization (net of tax) (792 ) Total reclassifications for the period (net of tax) ($792 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.
Entergy Louisiana [Member]
Equity	EQUITY (Entergy Corporation and Entergy Louisiana) Common Stock Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Three Months Ended June 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $567.3 178.8 $3.17 $148.8 179.5 $0.83 Average dilutive effect of: Stock options 0.2 — 0.2 — Other equity plans 0.5 (0.01 ) 0.4 — Diluted earnings per share $567.3 179.5 $3.16 $148.8 180.1 $0.83 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 4.1 million for the three months ended June 30, 2016 and approximately 5.1 million for the three months ended June 30, 2015 . For the Six Months Ended June 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $797.3 178.7 $4.46 $446.9 179.6 $2.49 Average dilutive effect of: Stock options 0.1 — 0.4 (0.01 ) Other equity plans 0.4 (0.01 ) 0.3 — Diluted earnings per share $797.3 179.2 $4.45 $446.9 180.3 $2.48 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 5.1 million for the six months ended June 30, 2016 and approximately 4.3 million for the six months ended June 30, 2015 . Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K. Treasury Stock During the six months ended June 30, 2016 , Entergy Corporation issued 507,144 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards. Entergy Corporation did not repurchase any of its common stock during the six months ended June 30, 2016 . Retained Earnings On July 29, 2016, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.85 per share, payable on September 1, 2016, to holders of record as of August 11, 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 June 30, 2016 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, April 1, 2016 $96,464 ($459,042 ) $390,626 $1,744 $29,792 Other comprehensive income (loss) before reclassifications (34,138 ) — 24,016 (904 ) (11,026 ) Amounts reclassified from accumulated other comprehensive income (loss) (29,903 ) 5,043 (3,061 ) — (27,921 ) Net other comprehensive income (loss) for the period (64,041 ) 5,043 20,955 (904 ) (38,947 ) Ending balance, June 30, 2016 $32,423 ($453,999 ) $411,581 $840 ($9,155 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 2015 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, April 1, 2015 $68,788 ($561,341 ) $430,698 $2,118 ($59,737 ) Other comprehensive income (loss) before reclassifications 88,796 — (25,108 ) 667 64,355 Amounts reclassified from accumulated other comprehensive income (loss) (50,100 ) 7,438 (8,772 ) — (51,434 ) Net other comprehensive income (loss) for the period 38,696 7,438 (33,880 ) 667 12,921 Ending balance, June 30, 2015 $107,484 ($553,903 ) $396,818 $2,785 ($46,816 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2016 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, January 1, 2016 $105,970 ($466,604 ) $367,557 $2,028 $8,951 Other comprehensive income (loss) before reclassifications 56,169 — 49,048 (1,188 ) 104,029 Amounts reclassified from accumulated other comprehensive income (loss) (129,716 ) 12,605 (5,024 ) — (122,135 ) Net other comprehensive income (loss) for the period (73,547 ) 12,605 44,024 (1,188 ) (18,106 ) Ending balance, June 30, 2016 $32,423 ($453,999 ) $411,581 $840 ($9,155 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2015 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, January 1, 2015 $98,118 ($569,789 ) $426,695 $2,669 ($42,307 ) Other comprehensive income (loss) before reclassifications 67,900 13 (12,450 ) 116 55,579 Amounts reclassified from accumulated other comprehensive income (loss) (58,534 ) 15,873 (17,427 ) — (60,088 ) Net other comprehensive income (loss) for the period 9,366 15,886 (29,877 ) 116 (4,509 ) Ending balance, June 30, 2015 $107,484 ($553,903 ) $396,818 $2,785 ($46,816 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended June 30, 2016: Pension and Other (In Thousands) Beginning balance April 1, 2016 ($56,675 ) Amounts reclassified from accumulated other (230 ) Net other comprehensive income (loss) for the period (230 ) Ending balance, June 30, 2016 ($56,905 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended June 30, 2015: Pension and Other (In Thousands) Beginning balance April 1, 2015 ($78,843 ) Amounts reclassified from accumulated other 412 Net other comprehensive income (loss) for the period 412 Ending balance, June 30, 2015 ($78,431 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2016: Pension and Other (In Thousands) Beginning balance, January 1, 2016 ($56,412 ) Amounts reclassified from accumulated other (493 ) Net other comprehensive income (loss) for the period (493 ) Ending balance, June 30, 2016 ($56,905 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2015: Pension and Other (In Thousands) Beginning balance, January 1, 2015 ($79,223 ) Amounts reclassified from accumulated other 792 Net other comprehensive income (loss) for the period 792 Ending balance, June 30, 2015 ($78,431 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended June 30, 2016 are as follows: Amounts reclassified from AOCI Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $45,975 Competitive business operating revenues Interest rate swaps 30 Miscellaneous - net Total realized gain (loss) on cash flow hedges 46,005 (16,102 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $29,903 Pension and other postretirement liabilities Amortization of prior-service credit $7,355 (a) Amortization of loss (15,177 ) (a) Total amortization (7,822 ) 2,779 Income taxes Total amortization (net of tax) ($5,043 ) Net unrealized investment gain (loss) Realized gain (loss) $6,000 Interest and investment income (2,939 ) Income taxes Total realized investment gain (loss) (net of tax) $3,061 Total reclassifications for the period (net of tax) $27,921 (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 June 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $77,587 Competitive business operating revenues Interest rate swaps (510 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 77,077 (26,977 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $50,100 Pension and other postretirement liabilities Amortization of prior-service credit $5,985 (a) Amortization of loss (17,588 ) (a) Total amortization (11,603 ) 4,165 Income taxes Total amortization (net of tax) ($7,438 ) Net unrealized investment gain (loss) Realized gain (loss) $17,201 Interest and investment income (8,429 ) Income taxes Total realized investment gain (loss) (net of tax) $8,772 Total reclassifications for the period (net of tax) $51,434 (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 six months ended June 30, 2016 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $199,933 Competitive business operating revenues Interest rate swaps (370 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 199,563 (69,847 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $129,716 Pension and other postretirement liabilities Amortization of prior-service credit $14,710 (a) Amortization of loss (30,352 ) (a) Total amortization (15,642 ) 3,037 Income taxes Total amortization (net of tax) ($12,605 ) Net unrealized investment gain (loss) Realized gain (loss) $9,850 Interest and investment income (4,826 ) Income taxes Total realized investment gain (loss) (net of tax) $5,024 Total reclassifications for the period (net of tax) $122,135 (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 six months ended June 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $91,109 Competitive business operating revenues Interest rate swaps (1,056 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 90,053 (31,519 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $58,534 Pension and other postretirement liabilities Amortization of prior-service credit $11,971 (a) Amortization of loss (35,176 ) (a) Total amortization (23,205 ) 7,332 Income taxes Total amortization (net of tax) ($15,873 ) Net unrealized investment gain (loss) Realized gain (loss) $34,171 Interest and investment income (16,744 ) Income taxes Total realized investment gain (loss) (net of tax) $17,427 Total reclassifications for the period (net of tax) $60,088 (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 June 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,947 (a) Amortization of loss (1,573 ) (a) Total amortization 374 (144 ) Income taxes Total amortization (net of tax) 230 Total reclassifications for the period (net of tax) $230 (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 June 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,866 (a) Amortization of loss (2,535 ) (a) Total amortization (669 ) 257 Income taxes Total amortization (net of tax) (412 ) Total reclassifications for the period (net of tax) ($412 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the six months ended June 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $3,894 (a) Amortization of loss (3,142 ) (a) Total amortization 752 (259 ) Income taxes Total amortization (net of tax) 493 Total reclassifications for the period (net of tax) $493 (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 six months ended June 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $3,733 (a) Amortization of loss (5,070 ) (a) Total amortization (1,337 ) 545 Income taxes Total amortization (net of tax) (792 ) Total reclassifications for the period (net of tax) ($792 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.

Revolving Credit Facilities, Li

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	6 Months Ended
	Jun. 30, 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 six months ended June 30, 2016 was 2.28% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $240 $6 $3,254 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 June 30, 2016 , Entergy Corporation had $853 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2016 was 1.13% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2016 Letters of Credit Outstanding as of June 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.71% $— $— Entergy Arkansas August 2020 $150 million (c) 1.71% $— $— Entergy Louisiana August 2020 $350 million (d) 1.71% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 1.96% $— $— Entergy Mississippi May 2017 $35 million (e) 1.96% $— $— Entergy Mississippi May 2017 $20 million (e) 1.96% $— $— Entergy Mississippi May 2017 $10 million (e) 1.96% $— $— Entergy New Orleans November 2018 $25 million (f) 2.21% $— $— Entergy Texas August 2020 $150 million (g) 1.96% $— $1.3 million (a) The interest rate is the rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations related to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $59.1 million Entergy Mississippi $40 million 0.70% $26.7 million Entergy New Orleans $15 million 0.75% $13.3 million Entergy Texas $50 million 0.70% $14.4 million (a) The amount for Entergy Texas includes $1.4 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 June 30, 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 Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2017. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2018. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through June 2018. Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee 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 June 30, 2016 , $59 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2016 was 2.21% 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 June 30, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility was 2.21% 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 June 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.075% $12.6 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 1.95% $59.5 (b) System Energy VIE May 2019 $120 2.075% $99.6 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas and Entergy Louisiana VIEs and 0.125% of the undrawn commitment amount for the System Energy VIE. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 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 the Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In June 2016, Entergy Arkansas issued $55 million of 3.5% Series first mortgage bonds due April 2026. These bonds were a further issuance of the 3.5% Series first mortgage bonds issued in January 2016. In July 2016, Entergy Arkansas used the proceeds, together with other funds, to pay, prior to maturity, its $60 million of 6.38% Series first mortgage bonds due November 2034 and for general corporate purposes. In July 2016 the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $55 million of 3.23% Series J notes. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. These bonds were a further issuance of the 4.95% Series first mortgage bonds issued in November 2014. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, to repay borrowings under its $350 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana issued $425 million of 3.25% Series collateral trust mortgage bonds due April 2028. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana arranged for the issuance by the Louisiana Public Facilities Authority of (i) $83.680 million of 3.375% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016A due September 2028, and (ii) $115 million of 3.50% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016B due June 2030, each of which series is evidenced by a separate series of non-interest bearing collateral trust mortgage bonds of Entergy Louisiana. The proceeds from these issuances were applied in April 2016 to the refunding of $198.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. In March 2016, Entergy Louisiana issued $51.972 million of Waterford Series collateral trust mortgage notes due July 2017 as part of the purchase of the undivided interests in Waterford 3. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction. In March 2016 the Entergy Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $20 million of 3.30% Series F notes. In May 2016, Entergy Louisiana issued $325 million of 3.05% Series collateral trust mortgage bonds due June 2031. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $240 million of 6.2% Series first mortgage bonds due July 2033 and its $85 million of 6.18% Series first mortgage bonds due March 2035, and for general corporate purposes. (Entergy Mississippi) In May 2016, Entergy Mississippi issued $375 million of 2.85% Series first mortgage bonds due June 2028. Entergy Mississippi used the proceeds to pay, at maturity, its $125 million of 3.25% Series first mortgage bonds due June 2016, to pay, prior to maturity, its $75 million of 6.0% Series first mortgage bonds due November 2032, and its $100 million of 6.25% Series first mortgage bonds due April 2034, and to cause the repayment of the $30 million of 4.90% pollution control revenue bonds due 2022 issued on behalf of Entergy Mississippi, and for general corporate purposes. (Entergy New Orleans) In March 2016, Entergy New Orleans issued $110 million of 5.50% Series first mortgage bonds due April 2066. Entergy New Orleans used the proceeds to repay borrowings from the money pool, to repay borrowings under its $25 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Block 1 of the Union Power Station. See Note 13 to the financial statements for discussion of the Union Power Station purchase. In May 2016, Entergy New Orleans issued $85 million of 4% Series first mortgage bonds due June 2026. Entergy New Orleans used the proceeds to pay, prior to maturity, its $33.271 million of 5.6% Series first mortgage bonds due September 2024, to pay, prior to maturity, its $37.772 million of 5.65% Series first mortgage bonds due September 2029, and for general corporate purposes. (Entergy Texas) In March 2016, Entergy Texas issued $125 million of 2.55% Series first mortgage bonds due June 2021. Entergy Texas used the proceeds for general corporate purposes. (System Energy) In May 2016, System Energy caused the repayment of $22 million of its $156 million of 5.875% pollution control revenue bonds due 2022 issued on behalf of System Energy. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,783,804 $14,556,026 Entergy Arkansas $2,830,658 $2,835,020 Entergy Louisiana $5,410,218 $5,859,090 Entergy Mississippi $1,091,938 $1,153,791 Entergy New Orleans $459,095 $466,368 Entergy Texas $1,539,889 $1,704,985 System Energy $550,926 $543,935 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 million at Entergy Arkansas, and 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 six months ended June 30, 2016 was 2.28% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $240 $6 $3,254 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 June 30, 2016 , Entergy Corporation had $853 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2016 was 1.13% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2016 Letters of Credit Outstanding as of June 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.71% $— $— Entergy Arkansas August 2020 $150 million (c) 1.71% $— $— Entergy Louisiana August 2020 $350 million (d) 1.71% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 1.96% $— $— Entergy Mississippi May 2017 $35 million (e) 1.96% $— $— Entergy Mississippi May 2017 $20 million (e) 1.96% $— $— Entergy Mississippi May 2017 $10 million (e) 1.96% $— $— Entergy New Orleans November 2018 $25 million (f) 2.21% $— $— Entergy Texas August 2020 $150 million (g) 1.96% $— $1.3 million (a) The interest rate is the rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations related to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $59.1 million Entergy Mississippi $40 million 0.70% $26.7 million Entergy New Orleans $15 million 0.75% $13.3 million Entergy Texas $50 million 0.70% $14.4 million (a) The amount for Entergy Texas includes $1.4 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 June 30, 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 Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2017. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2018. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through June 2018. Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee 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 June 30, 2016 , $59 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2016 was 2.21% 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 June 30, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility was 2.21% 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 June 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.075% $12.6 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 1.95% $59.5 (b) System Energy VIE May 2019 $120 2.075% $99.6 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas and Entergy Louisiana VIEs and 0.125% of the undrawn commitment amount for the System Energy VIE. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 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 the Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In June 2016, Entergy Arkansas issued $55 million of 3.5% Series first mortgage bonds due April 2026. These bonds were a further issuance of the 3.5% Series first mortgage bonds issued in January 2016. In July 2016, Entergy Arkansas used the proceeds, together with other funds, to pay, prior to maturity, its $60 million of 6.38% Series first mortgage bonds due November 2034 and for general corporate purposes. In July 2016 the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $55 million of 3.23% Series J notes. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. These bonds were a further issuance of the 4.95% Series first mortgage bonds issued in November 2014. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, to repay borrowings under its $350 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana issued $425 million of 3.25% Series collateral trust mortgage bonds due April 2028. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana arranged for the issuance by the Louisiana Public Facilities Authority of (i) $83.680 million of 3.375% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016A due September 2028, and (ii) $115 million of 3.50% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016B due June 2030, each of which series is evidenced by a separate series of non-interest bearing collateral trust mortgage bonds of Entergy Louisiana. The proceeds from these issuances were applied in April 2016 to the refunding of $198.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. In March 2016, Entergy Louisiana issued $51.972 million of Waterford Series collateral trust mortgage notes due July 2017 as part of the purchase of the undivided interests in Waterford 3. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction. In March 2016 the Entergy Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $20 million of 3.30% Series F notes. In May 2016, Entergy Louisiana issued $325 million of 3.05% Series collateral trust mortgage bonds due June 2031. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $240 million of 6.2% Series first mortgage bonds due July 2033 and its $85 million of 6.18% Series first mortgage bonds due March 2035, and for general corporate purposes. (Entergy Mississippi) In May 2016, Entergy Mississippi issued $375 million of 2.85% Series first mortgage bonds due June 2028. Entergy Mississippi used the proceeds to pay, at maturity, its $125 million of 3.25% Series first mortgage bonds due June 2016, to pay, prior to maturity, its $75 million of 6.0% Series first mortgage bonds due November 2032, and its $100 million of 6.25% Series first mortgage bonds due April 2034, and to cause the repayment of the $30 million of 4.90% pollution control revenue bonds due 2022 issued on behalf of Entergy Mississippi, and for general corporate purposes. (Entergy New Orleans) In March 2016, Entergy New Orleans issued $110 million of 5.50% Series first mortgage bonds due April 2066. Entergy New Orleans used the proceeds to repay borrowings from the money pool, to repay borrowings under its $25 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Block 1 of the Union Power Station. See Note 13 to the financial statements for discussion of the Union Power Station purchase. In May 2016, Entergy New Orleans issued $85 million of 4% Series first mortgage bonds due June 2026. Entergy New Orleans used the proceeds to pay, prior to maturity, its $33.271 million of 5.6% Series first mortgage bonds due September 2024, to pay, prior to maturity, its $37.772 million of 5.65% Series first mortgage bonds due September 2029, and for general corporate purposes. (Entergy Texas) In March 2016, Entergy Texas issued $125 million of 2.55% Series first mortgage bonds due June 2021. Entergy Texas used the proceeds for general corporate purposes. (System Energy) In May 2016, System Energy caused the repayment of $22 million of its $156 million of 5.875% pollution control revenue bonds due 2022 issued on behalf of System Energy. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,783,804 $14,556,026 Entergy Arkansas $2,830,658 $2,835,020 Entergy Louisiana $5,410,218 $5,859,090 Entergy Mississippi $1,091,938 $1,153,791 Entergy New Orleans $459,095 $466,368 Entergy Texas $1,539,889 $1,704,985 System Energy $550,926 $543,935 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 million at Entergy Arkansas, and 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 six months ended June 30, 2016 was 2.28% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $240 $6 $3,254 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 June 30, 2016 , Entergy Corporation had $853 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2016 was 1.13% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2016 Letters of Credit Outstanding as of June 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.71% $— $— Entergy Arkansas August 2020 $150 million (c) 1.71% $— $— Entergy Louisiana August 2020 $350 million (d) 1.71% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 1.96% $— $— Entergy Mississippi May 2017 $35 million (e) 1.96% $— $— Entergy Mississippi May 2017 $20 million (e) 1.96% $— $— Entergy Mississippi May 2017 $10 million (e) 1.96% $— $— Entergy New Orleans November 2018 $25 million (f) 2.21% $— $— Entergy Texas August 2020 $150 million (g) 1.96% $— $1.3 million (a) The interest rate is the rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations related to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $59.1 million Entergy Mississippi $40 million 0.70% $26.7 million Entergy New Orleans $15 million 0.75% $13.3 million Entergy Texas $50 million 0.70% $14.4 million (a) The amount for Entergy Texas includes $1.4 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 June 30, 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 Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2017. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2018. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through June 2018. Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee 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 June 30, 2016 , $59 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2016 was 2.21% 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 June 30, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility was 2.21% 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 June 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.075% $12.6 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 1.95% $59.5 (b) System Energy VIE May 2019 $120 2.075% $99.6 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas and Entergy Louisiana VIEs and 0.125% of the undrawn commitment amount for the System Energy VIE. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 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 the Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In June 2016, Entergy Arkansas issued $55 million of 3.5% Series first mortgage bonds due April 2026. These bonds were a further issuance of the 3.5% Series first mortgage bonds issued in January 2016. In July 2016, Entergy Arkansas used the proceeds, together with other funds, to pay, prior to maturity, its $60 million of 6.38% Series first mortgage bonds due November 2034 and for general corporate purposes. In July 2016 the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $55 million of 3.23% Series J notes. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. These bonds were a further issuance of the 4.95% Series first mortgage bonds issued in November 2014. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, to repay borrowings under its $350 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana issued $425 million of 3.25% Series collateral trust mortgage bonds due April 2028. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana arranged for the issuance by the Louisiana Public Facilities Authority of (i) $83.680 million of 3.375% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016A due September 2028, and (ii) $115 million of 3.50% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016B due June 2030, each of which series is evidenced by a separate series of non-interest bearing collateral trust mortgage bonds of Entergy Louisiana. The proceeds from these issuances were applied in April 2016 to the refunding of $198.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. In March 2016, Entergy Louisiana issued $51.972 million of Waterford Series collateral trust mortgage notes due July 2017 as part of the purchase of the undivided interests in Waterford 3. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction. In March 2016 the Entergy Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $20 million of 3.30% Series F notes. In May 2016, Entergy Louisiana issued $325 million of 3.05% Series collateral trust mortgage bonds due June 2031. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $240 million of 6.2% Series first mortgage bonds due July 2033 and its $85 million of 6.18% Series first mortgage bonds due March 2035, and for general corporate purposes. (Entergy Mississippi) In May 2016, Entergy Mississippi issued $375 million of 2.85% Series first mortgage bonds due June 2028. Entergy Mississippi used the proceeds to pay, at maturity, its $125 million of 3.25% Series first mortgage bonds due June 2016, to pay, prior to maturity, its $75 million of 6.0% Series first mortgage bonds due November 2032, and its $100 million of 6.25% Series first mortgage bonds due April 2034, and to cause the repayment of the $30 million of 4.90% pollution control revenue bonds due 2022 issued on behalf of Entergy Mississippi, and for general corporate purposes. (Entergy New Orleans) In March 2016, Entergy New Orleans issued $110 million of 5.50% Series first mortgage bonds due April 2066. Entergy New Orleans used the proceeds to repay borrowings from the money pool, to repay borrowings under its $25 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Block 1 of the Union Power Station. See Note 13 to the financial statements for discussion of the Union Power Station purchase. In May 2016, Entergy New Orleans issued $85 million of 4% Series first mortgage bonds due June 2026. Entergy New Orleans used the proceeds to pay, prior to maturity, its $33.271 million of 5.6% Series first mortgage bonds due September 2024, to pay, prior to maturity, its $37.772 million of 5.65% Series first mortgage bonds due September 2029, and for general corporate purposes. (Entergy Texas) In March 2016, Entergy Texas issued $125 million of 2.55% Series first mortgage bonds due June 2021. Entergy Texas used the proceeds for general corporate purposes. (System Energy) In May 2016, System Energy caused the repayment of $22 million of its $156 million of 5.875% pollution control revenue bonds due 2022 issued on behalf of System Energy. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,783,804 $14,556,026 Entergy Arkansas $2,830,658 $2,835,020 Entergy Louisiana $5,410,218 $5,859,090 Entergy Mississippi $1,091,938 $1,153,791 Entergy New Orleans $459,095 $466,368 Entergy Texas $1,539,889 $1,704,985 System Energy $550,926 $543,935 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 million at Entergy Arkansas, and 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 six months ended June 30, 2016 was 2.28% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $240 $6 $3,254 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 June 30, 2016 , Entergy Corporation had $853 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2016 was 1.13% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2016 Letters of Credit Outstanding as of June 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.71% $— $— Entergy Arkansas August 2020 $150 million (c) 1.71% $— $— Entergy Louisiana August 2020 $350 million (d) 1.71% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 1.96% $— $— Entergy Mississippi May 2017 $35 million (e) 1.96% $— $— Entergy Mississippi May 2017 $20 million (e) 1.96% $— $— Entergy Mississippi May 2017 $10 million (e) 1.96% $— $— Entergy New Orleans November 2018 $25 million (f) 2.21% $— $— Entergy Texas August 2020 $150 million (g) 1.96% $— $1.3 million (a) The interest rate is the rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations related to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $59.1 million Entergy Mississippi $40 million 0.70% $26.7 million Entergy New Orleans $15 million 0.75% $13.3 million Entergy Texas $50 million 0.70% $14.4 million (a) The amount for Entergy Texas includes $1.4 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 June 30, 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 Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2017. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2018. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through June 2018. Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee 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 June 30, 2016 , $59 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2016 was 2.21% 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 June 30, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility was 2.21% 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 June 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.075% $12.6 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 1.95% $59.5 (b) System Energy VIE May 2019 $120 2.075% $99.6 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas and Entergy Louisiana VIEs and 0.125% of the undrawn commitment amount for the System Energy VIE. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 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 the Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In June 2016, Entergy Arkansas issued $55 million of 3.5% Series first mortgage bonds due April 2026. These bonds were a further issuance of the 3.5% Series first mortgage bonds issued in January 2016. In July 2016, Entergy Arkansas used the proceeds, together with other funds, to pay, prior to maturity, its $60 million of 6.38% Series first mortgage bonds due November 2034 and for general corporate purposes. In July 2016 the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $55 million of 3.23% Series J notes. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. These bonds were a further issuance of the 4.95% Series first mortgage bonds issued in November 2014. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, to repay borrowings under its $350 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana issued $425 million of 3.25% Series collateral trust mortgage bonds due April 2028. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana arranged for the issuance by the Louisiana Public Facilities Authority of (i) $83.680 million of 3.375% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016A due September 2028, and (ii) $115 million of 3.50% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016B due June 2030, each of which series is evidenced by a separate series of non-interest bearing collateral trust mortgage bonds of Entergy Louisiana. The proceeds from these issuances were applied in April 2016 to the refunding of $198.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. In March 2016, Entergy Louisiana issued $51.972 million of Waterford Series collateral trust mortgage notes due July 2017 as part of the purchase of the undivided interests in Waterford 3. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction. In March 2016 the Entergy Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $20 million of 3.30% Series F notes. In May 2016, Entergy Louisiana issued $325 million of 3.05% Series collateral trust mortgage bonds due June 2031. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $240 million of 6.2% Series first mortgage bonds due July 2033 and its $85 million of 6.18% Series first mortgage bonds due March 2035, and for general corporate purposes. (Entergy Mississippi) In May 2016, Entergy Mississippi issued $375 million of 2.85% Series first mortgage bonds due June 2028. Entergy Mississippi used the proceeds to pay, at maturity, its $125 million of 3.25% Series first mortgage bonds due June 2016, to pay, prior to maturity, its $75 million of 6.0% Series first mortgage bonds due November 2032, and its $100 million of 6.25% Series first mortgage bonds due April 2034, and to cause the repayment of the $30 million of 4.90% pollution control revenue bonds due 2022 issued on behalf of Entergy Mississippi, and for general corporate purposes. (Entergy New Orleans) In March 2016, Entergy New Orleans issued $110 million of 5.50% Series first mortgage bonds due April 2066. Entergy New Orleans used the proceeds to repay borrowings from the money pool, to repay borrowings under its $25 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Block 1 of the Union Power Station. See Note 13 to the financial statements for discussion of the Union Power Station purchase. In May 2016, Entergy New Orleans issued $85 million of 4% Series first mortgage bonds due June 2026. Entergy New Orleans used the proceeds to pay, prior to maturity, its $33.271 million of 5.6% Series first mortgage bonds due September 2024, to pay, prior to maturity, its $37.772 million of 5.65% Series first mortgage bonds due September 2029, and for general corporate purposes. (Entergy Texas) In March 2016, Entergy Texas issued $125 million of 2.55% Series first mortgage bonds due June 2021. Entergy Texas used the proceeds for general corporate purposes. (System Energy) In May 2016, System Energy caused the repayment of $22 million of its $156 million of 5.875% pollution control revenue bonds due 2022 issued on behalf of System Energy. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,783,804 $14,556,026 Entergy Arkansas $2,830,658 $2,835,020 Entergy Louisiana $5,410,218 $5,859,090 Entergy Mississippi $1,091,938 $1,153,791 Entergy New Orleans $459,095 $466,368 Entergy Texas $1,539,889 $1,704,985 System Energy $550,926 $543,935 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 million at Entergy Arkansas, and 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 six months ended June 30, 2016 was 2.28% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $240 $6 $3,254 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 June 30, 2016 , Entergy Corporation had $853 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2016 was 1.13% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2016 Letters of Credit Outstanding as of June 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.71% $— $— Entergy Arkansas August 2020 $150 million (c) 1.71% $— $— Entergy Louisiana August 2020 $350 million (d) 1.71% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 1.96% $— $— Entergy Mississippi May 2017 $35 million (e) 1.96% $— $— Entergy Mississippi May 2017 $20 million (e) 1.96% $— $— Entergy Mississippi May 2017 $10 million (e) 1.96% $— $— Entergy New Orleans November 2018 $25 million (f) 2.21% $— $— Entergy Texas August 2020 $150 million (g) 1.96% $— $1.3 million (a) The interest rate is the rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations related to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $59.1 million Entergy Mississippi $40 million 0.70% $26.7 million Entergy New Orleans $15 million 0.75% $13.3 million Entergy Texas $50 million 0.70% $14.4 million (a) The amount for Entergy Texas includes $1.4 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 June 30, 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 Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2017. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2018. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through June 2018. Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee 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 June 30, 2016 , $59 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2016 was 2.21% 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 June 30, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility was 2.21% 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 June 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.075% $12.6 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 1.95% $59.5 (b) System Energy VIE May 2019 $120 2.075% $99.6 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas and Entergy Louisiana VIEs and 0.125% of the undrawn commitment amount for the System Energy VIE. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 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 the Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In June 2016, Entergy Arkansas issued $55 million of 3.5% Series first mortgage bonds due April 2026. These bonds were a further issuance of the 3.5% Series first mortgage bonds issued in January 2016. In July 2016, Entergy Arkansas used the proceeds, together with other funds, to pay, prior to maturity, its $60 million of 6.38% Series first mortgage bonds due November 2034 and for general corporate purposes. In July 2016 the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $55 million of 3.23% Series J notes. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. These bonds were a further issuance of the 4.95% Series first mortgage bonds issued in November 2014. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, to repay borrowings under its $350 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana issued $425 million of 3.25% Series collateral trust mortgage bonds due April 2028. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana arranged for the issuance by the Louisiana Public Facilities Authority of (i) $83.680 million of 3.375% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016A due September 2028, and (ii) $115 million of 3.50% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016B due June 2030, each of which series is evidenced by a separate series of non-interest bearing collateral trust mortgage bonds of Entergy Louisiana. The proceeds from these issuances were applied in April 2016 to the refunding of $198.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. In March 2016, Entergy Louisiana issued $51.972 million of Waterford Series collateral trust mortgage notes due July 2017 as part of the purchase of the undivided interests in Waterford 3. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction. In March 2016 the Entergy Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $20 million of 3.30% Series F notes. In May 2016, Entergy Louisiana issued $325 million of 3.05% Series collateral trust mortgage bonds due June 2031. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $240 million of 6.2% Series first mortgage bonds due July 2033 and its $85 million of 6.18% Series first mortgage bonds due March 2035, and for general corporate purposes. (Entergy Mississippi) In May 2016, Entergy Mississippi issued $375 million of 2.85% Series first mortgage bonds due June 2028. Entergy Mississippi used the proceeds to pay, at maturity, its $125 million of 3.25% Series first mortgage bonds due June 2016, to pay, prior to maturity, its $75 million of 6.0% Series first mortgage bonds due November 2032, and its $100 million of 6.25% Series first mortgage bonds due April 2034, and to cause the repayment of the $30 million of 4.90% pollution control revenue bonds due 2022 issued on behalf of Entergy Mississippi, and for general corporate purposes. (Entergy New Orleans) In March 2016, Entergy New Orleans issued $110 million of 5.50% Series first mortgage bonds due April 2066. Entergy New Orleans used the proceeds to repay borrowings from the money pool, to repay borrowings under its $25 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Block 1 of the Union Power Station. See Note 13 to the financial statements for discussion of the Union Power Station purchase. In May 2016, Entergy New Orleans issued $85 million of 4% Series first mortgage bonds due June 2026. Entergy New Orleans used the proceeds to pay, prior to maturity, its $33.271 million of 5.6% Series first mortgage bonds due September 2024, to pay, prior to maturity, its $37.772 million of 5.65% Series first mortgage bonds due September 2029, and for general corporate purposes. (Entergy Texas) In March 2016, Entergy Texas issued $125 million of 2.55% Series first mortgage bonds due June 2021. Entergy Texas used the proceeds for general corporate purposes. (System Energy) In May 2016, System Energy caused the repayment of $22 million of its $156 million of 5.875% pollution control revenue bonds due 2022 issued on behalf of System Energy. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,783,804 $14,556,026 Entergy Arkansas $2,830,658 $2,835,020 Entergy Louisiana $5,410,218 $5,859,090 Entergy Mississippi $1,091,938 $1,153,791 Entergy New Orleans $459,095 $466,368 Entergy Texas $1,539,889 $1,704,985 System Energy $550,926 $543,935 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 million at Entergy Arkansas, and 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 six months ended June 30, 2016 was 2.28% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $240 $6 $3,254 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 June 30, 2016 , Entergy Corporation had $853 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2016 was 1.13% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2016 Letters of Credit Outstanding as of June 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.71% $— $— Entergy Arkansas August 2020 $150 million (c) 1.71% $— $— Entergy Louisiana August 2020 $350 million (d) 1.71% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 1.96% $— $— Entergy Mississippi May 2017 $35 million (e) 1.96% $— $— Entergy Mississippi May 2017 $20 million (e) 1.96% $— $— Entergy Mississippi May 2017 $10 million (e) 1.96% $— $— Entergy New Orleans November 2018 $25 million (f) 2.21% $— $— Entergy Texas August 2020 $150 million (g) 1.96% $— $1.3 million (a) The interest rate is the rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations related to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $59.1 million Entergy Mississippi $40 million 0.70% $26.7 million Entergy New Orleans $15 million 0.75% $13.3 million Entergy Texas $50 million 0.70% $14.4 million (a) The amount for Entergy Texas includes $1.4 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 June 30, 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 Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2017. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2018. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through June 2018. Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee 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 June 30, 2016 , $59 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2016 was 2.21% 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 June 30, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility was 2.21% 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 June 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.075% $12.6 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 1.95% $59.5 (b) System Energy VIE May 2019 $120 2.075% $99.6 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas and Entergy Louisiana VIEs and 0.125% of the undrawn commitment amount for the System Energy VIE. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 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 the Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In June 2016, Entergy Arkansas issued $55 million of 3.5% Series first mortgage bonds due April 2026. These bonds were a further issuance of the 3.5% Series first mortgage bonds issued in January 2016. In July 2016, Entergy Arkansas used the proceeds, together with other funds, to pay, prior to maturity, its $60 million of 6.38% Series first mortgage bonds due November 2034 and for general corporate purposes. In July 2016 the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $55 million of 3.23% Series J notes. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. These bonds were a further issuance of the 4.95% Series first mortgage bonds issued in November 2014. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, to repay borrowings under its $350 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana issued $425 million of 3.25% Series collateral trust mortgage bonds due April 2028. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana arranged for the issuance by the Louisiana Public Facilities Authority of (i) $83.680 million of 3.375% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016A due September 2028, and (ii) $115 million of 3.50% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016B due June 2030, each of which series is evidenced by a separate series of non-interest bearing collateral trust mortgage bonds of Entergy Louisiana. The proceeds from these issuances were applied in April 2016 to the refunding of $198.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. In March 2016, Entergy Louisiana issued $51.972 million of Waterford Series collateral trust mortgage notes due July 2017 as part of the purchase of the undivided interests in Waterford 3. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction. In March 2016 the Entergy Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $20 million of 3.30% Series F notes. In May 2016, Entergy Louisiana issued $325 million of 3.05% Series collateral trust mortgage bonds due June 2031. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $240 million of 6.2% Series first mortgage bonds due July 2033 and its $85 million of 6.18% Series first mortgage bonds due March 2035, and for general corporate purposes. (Entergy Mississippi) In May 2016, Entergy Mississippi issued $375 million of 2.85% Series first mortgage bonds due June 2028. Entergy Mississippi used the proceeds to pay, at maturity, its $125 million of 3.25% Series first mortgage bonds due June 2016, to pay, prior to maturity, its $75 million of 6.0% Series first mortgage bonds due November 2032, and its $100 million of 6.25% Series first mortgage bonds due April 2034, and to cause the repayment of the $30 million of 4.90% pollution control revenue bonds due 2022 issued on behalf of Entergy Mississippi, and for general corporate purposes. (Entergy New Orleans) In March 2016, Entergy New Orleans issued $110 million of 5.50% Series first mortgage bonds due April 2066. Entergy New Orleans used the proceeds to repay borrowings from the money pool, to repay borrowings under its $25 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Block 1 of the Union Power Station. See Note 13 to the financial statements for discussion of the Union Power Station purchase. In May 2016, Entergy New Orleans issued $85 million of 4% Series first mortgage bonds due June 2026. Entergy New Orleans used the proceeds to pay, prior to maturity, its $33.271 million of 5.6% Series first mortgage bonds due September 2024, to pay, prior to maturity, its $37.772 million of 5.65% Series first mortgage bonds due September 2029, and for general corporate purposes. (Entergy Texas) In March 2016, Entergy Texas issued $125 million of 2.55% Series first mortgage bonds due June 2021. Entergy Texas used the proceeds for general corporate purposes. (System Energy) In May 2016, System Energy caused the repayment of $22 million of its $156 million of 5.875% pollution control revenue bonds due 2022 issued on behalf of System Energy. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,783,804 $14,556,026 Entergy Arkansas $2,830,658 $2,835,020 Entergy Louisiana $5,410,218 $5,859,090 Entergy Mississippi $1,091,938 $1,153,791 Entergy New Orleans $459,095 $466,368 Entergy Texas $1,539,889 $1,704,985 System Energy $550,926 $543,935 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 million at Entergy Arkansas, and 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 six months ended June 30, 2016 was 2.28% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $240 $6 $3,254 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 June 30, 2016 , Entergy Corporation had $853 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2016 was 1.13% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2016 Letters of Credit Outstanding as of June 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.71% $— $— Entergy Arkansas August 2020 $150 million (c) 1.71% $— $— Entergy Louisiana August 2020 $350 million (d) 1.71% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 1.96% $— $— Entergy Mississippi May 2017 $35 million (e) 1.96% $— $— Entergy Mississippi May 2017 $20 million (e) 1.96% $— $— Entergy Mississippi May 2017 $10 million (e) 1.96% $— $— Entergy New Orleans November 2018 $25 million (f) 2.21% $— $— Entergy Texas August 2020 $150 million (g) 1.96% $— $1.3 million (a) The interest rate is the rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations related to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $59.1 million Entergy Mississippi $40 million 0.70% $26.7 million Entergy New Orleans $15 million 0.75% $13.3 million Entergy Texas $50 million 0.70% $14.4 million (a) The amount for Entergy Texas includes $1.4 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 June 30, 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 Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2017. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2018. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through June 2018. Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee 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 June 30, 2016 , $59 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2016 was 2.21% 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 June 30, 2016 , there were no cash borrowings outstanding under the credit facility. The rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility was 2.21% 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 June 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.075% $12.6 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 1.95% $59.5 (b) System Energy VIE May 2019 $120 2.075% $99.6 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) Commercial paper, classified as a current liability. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas and Entergy Louisiana VIEs and 0.125% of the undrawn commitment amount for the System Energy VIE. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 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 the Union Power Station and for general corporate purposes. See Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In June 2016, Entergy Arkansas issued $55 million of 3.5% Series first mortgage bonds due April 2026. These bonds were a further issuance of the 3.5% Series first mortgage bonds issued in January 2016. In July 2016, Entergy Arkansas used the proceeds, together with other funds, to pay, prior to maturity, its $60 million of 6.38% Series first mortgage bonds due November 2034 and for general corporate purposes. In July 2016 the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $55 million of 3.23% Series J notes. (Entergy Louisiana) In March 2016, Entergy Louisiana issued $200 million of 4.95% Series first mortgage bonds due January 2045. These bonds were a further issuance of the 4.95% Series first mortgage bonds issued in November 2014. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, to repay borrowings under its $350 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana issued $425 million of 3.25% Series collateral trust mortgage bonds due April 2028. Entergy Louisiana used the proceeds to pay, together with other funds, the $60 million cash portion of the price to purchase the undivided interests of Waterford 3, to repay borrowings from the money pool, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Blocks 3 and 4 at the Union Power Station. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction and Note 13 to the financial statements herein for discussion of the Union Power Station purchase. In March 2016, Entergy Louisiana arranged for the issuance by the Louisiana Public Facilities Authority of (i) $83.680 million of 3.375% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016A due September 2028, and (ii) $115 million of 3.50% pollution control refunding revenue bonds (Entergy Louisiana, LLC Project) Series 2016B due June 2030, each of which series is evidenced by a separate series of non-interest bearing collateral trust mortgage bonds of Entergy Louisiana. The proceeds from these issuances were applied in April 2016 to the refunding of $198.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. In March 2016, Entergy Louisiana issued $51.972 million of Waterford Series collateral trust mortgage notes due July 2017 as part of the purchase of the undivided interests in Waterford 3. See Note 11 to the financial statements herein for discussion of the Waterford 3 transaction. In March 2016 the Entergy Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $20 million of 3.30% Series F notes. In May 2016, Entergy Louisiana issued $325 million of 3.05% Series collateral trust mortgage bonds due June 2031. Entergy Louisiana used the proceeds, together with other funds, to pay, prior to maturity, its $240 million of 6.2% Series first mortgage bonds due July 2033 and its $85 million of 6.18% Series first mortgage bonds due March 2035, and for general corporate purposes. (Entergy Mississippi) In May 2016, Entergy Mississippi issued $375 million of 2.85% Series first mortgage bonds due June 2028. Entergy Mississippi used the proceeds to pay, at maturity, its $125 million of 3.25% Series first mortgage bonds due June 2016, to pay, prior to maturity, its $75 million of 6.0% Series first mortgage bonds due November 2032, and its $100 million of 6.25% Series first mortgage bonds due April 2034, and to cause the repayment of the $30 million of 4.90% pollution control revenue bonds due 2022 issued on behalf of Entergy Mississippi, and for general corporate purposes. (Entergy New Orleans) In March 2016, Entergy New Orleans issued $110 million of 5.50% Series first mortgage bonds due April 2066. Entergy New Orleans used the proceeds to repay borrowings from the money pool, to repay borrowings under its $25 million credit facility, and for general corporate purposes. A portion of the proceeds of the borrowings described in the preceding sentence were used, together with other funds, for the purchase of Power Block 1 of the Union Power Station. See Note 13 to the financial statements for discussion of the Union Power Station purchase. In May 2016, Entergy New Orleans issued $85 million of 4% Series first mortgage bonds due June 2026. Entergy New Orleans used the proceeds to pay, prior to maturity, its $33.271 million of 5.6% Series first mortgage bonds due September 2024, to pay, prior to maturity, its $37.772 million of 5.65% Series first mortgage bonds due September 2029, and for general corporate purposes. (Entergy Texas) In March 2016, Entergy Texas issued $125 million of 2.55% Series first mortgage bonds due June 2021. Entergy Texas used the proceeds for general corporate purposes. (System Energy) In May 2016, System Energy caused the repayment of $22 million of its $156 million of 5.875% pollution control revenue bonds due 2022 issued on behalf of System Energy. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,783,804 $14,556,026 Entergy Arkansas $2,830,658 $2,835,020 Entergy Louisiana $5,410,218 $5,859,090 Entergy Mississippi $1,091,938 $1,153,791 Entergy New Orleans $459,095 $466,368 Entergy Texas $1,539,889 $1,704,985 System Energy $550,926 $543,935 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 million at Entergy Arkansas, and 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	6 Months Ended
	Jun. 30, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Stock-Based Compensation	STOCK-BASED COMPENSATION (Entergy Corporation) Entergy grants stock and stock-based awards, which are described more fully in Note 12 to the financial statements in the Form 10-K. Awards under Entergy’s plans generally vest over three years. Stock Options Entergy granted options on 696,900 shares of its common stock under the 2015 Equity Ownership Plan during the first quarter 2016 with a weighted-average fair value of $7.40 per option. As of June 30, 2016 , there were options on 7,386,878 shares of common stock outstanding with a weighted-average exercise price of $84.48 . The intrinsic value, which has no effect on net income, of the outstanding stock options is calculated by the positive difference between the weighted average exercise price of the stock options granted and Entergy Corporation’s common stock price as of June 30, 2016 . Because Entergy’s stock price at June 30, 2016 was less than the weighted average exercise price, the aggregate intrinsic value of the stock options outstanding as of June 30, 2016 was zero. The intrinsic value of all “in the money” stock options was $36.2 million as of June 30, 2016 . The following table includes financial information for outstanding stock options for the three months ended June 30, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $1.1 $1.0 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 The following table includes financial information for outstanding stock options for the six months ended June 30, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $2.2 $2.1 Tax benefit recognized in Entergy’s net income $0.8 $0.8 Compensation cost capitalized as part of fixed assets and inventory $0.4 $0.4 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 June 30, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $8.5 $8.0 Tax benefit recognized in Entergy’s net income $3.3 $3.1 Compensation cost capitalized as part of fixed assets and inventory $1.9 $1.6 The following table includes financial information for other outstanding equity awards for the six months ended June 30, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $16.9 $16.1 Tax benefit recognized in Entergy’s net income $6.5 $6.2 Compensation cost capitalized as part of fixed assets and inventory $3.7 $3.1

Retirement And Other Postretire

Retirement And Other Postretirement Benefits	6 Months Ended
	Jun. 30, 2016
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $71,622 $87,524 Interest cost on projected benefit obligation 130,806 151,388 Expected return on assets (194,732 ) (197,310 ) Amortization of prior service cost 540 780 Amortization of loss 97,648 117,962 Special termination benefit — 76 Net pension costs $105,884 $160,420 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,362 $14,098 $3,124 $1,312 $2,832 $3,132 Interest cost on projected benefit obligation 26,110 29,740 7,622 3,628 7,114 5,984 Expected return on assets (39,544 ) (44,192 ) (11,962 ) (5,374 ) (12,124 ) (8,918 ) Amortization of loss 21,872 23,892 5,970 3,230 4,680 5,208 Net pension cost $18,800 $23,538 $4,754 $2,796 $2,502 $5,406 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $13,322 $17,198 $3,964 $1,698 $3,290 $3,914 Interest cost on projected benefit obligation 30,942 34,734 9,004 4,216 8,708 6,986 Expected return on assets (40,052 ) (45,402 ) (12,210 ) (5,450 ) (12,444 ) (9,136 ) Amortization of loss 27,128 29,902 7,448 4,026 6,476 6,528 Net pension cost $31,340 $36,432 $8,206 $4,490 $6,030 $8,292 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 second quarters of 2016 and 2015 , respectively. Entergy recognized $8.5 million and $8.9 million in pension costs for its non-qualified pension plans for the six months ended June 30, 2016 and 2015, respectively. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the second quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost second quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost second quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost six months ended June 30, 2016 $212 $118 $118 $32 $254 Non-qualified pension cost six months ended June 30, 2015 $226 $136 $118 $32 $298 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $16,146 $22,652 Interest cost on accumulated postretirement benefit obligation (APBO) 28,166 35,968 Expected return on assets (20,910 ) (22,688 ) Amortization of prior service credit (22,746 ) (18,640 ) Amortization of loss 9,108 15,786 Net other postretirement benefit cost $9,764 $33,078 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,956 $3,738 $772 $312 $796 $668 Interest cost on APBO 4,648 6,520 1,418 896 2,078 1,058 Expected return on assets (8,928 ) — (2,758 ) (2,308 ) (4,788 ) (1,628 ) Amortization of prior service credit (2,736 ) (3,894 ) (468 ) (372 ) (1,362 ) (786 ) Amortization of loss 2,128 1,464 446 74 1,074 574 Net other postretirement benefit cost ($2,932 ) $7,828 ($590 ) ($1,398 ) ($2,202 ) ($114 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $3,478 $4,948 $1,014 $410 $1,000 $940 Interest cost on APBO 6,260 8,156 1,718 1,304 2,684 1,256 Expected return on assets (9,596 ) — (3,084 ) (2,402 ) (5,176 ) (1,822 ) Amortization of prior service credit (1,220 ) (3,734 ) (458 ) (354 ) (1,362 ) (732 ) Amortization of loss 2,678 3,560 430 236 1,370 600 Net other postretirement benefit cost $1,600 $12,930 ($380 ) ($806 ) ($1,484 ) $242 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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 ) (632 ) (15,177 ) ($12,752 ) $5,675 ($745 ) ($7,822 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (5 ) (1,573 ) ($836 ) $1,215 ($5 ) $374 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($6 ) ($669 ) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($540 ) $15,476 ($226 ) $14,710 Amortization of loss (24,964 ) (4,126 ) (1,262 ) (30,352 ) ($25,504 ) $11,350 ($1,488 ) ($15,642 ) Entergy Louisiana Amortization of prior service credit $— $3,894 $— $3,894 Amortization of loss (1,672 ) (1,464 ) (6 ) (3,142 ) ($1,672 ) $2,430 ($6 ) $752 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($778 ) $12,964 ($215 ) $11,971 Amortization of loss (25,254 ) (8,818 ) (1,104 ) (35,176 ) ($26,032 ) $4,146 ($1,319 ) ($23,205 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $3,734 ($1 ) $3,733 Amortization of loss (1,502 ) (3,558 ) (10 ) (5,070 ) ($1,502 ) $176 ($11 ) ($1,337 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of June 30, 2016 , Entergy had contributed $169.8 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 June 2016 $36,549 $37,319 $8,919 $4,680 $6,999 $8,891 Remaining estimated pension contributions to be made in 2016 $46,282 $46,590 $10,994 $6,014 $8,771 $11,315
Entergy Arkansas [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $71,622 $87,524 Interest cost on projected benefit obligation 130,806 151,388 Expected return on assets (194,732 ) (197,310 ) Amortization of prior service cost 540 780 Amortization of loss 97,648 117,962 Special termination benefit — 76 Net pension costs $105,884 $160,420 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,362 $14,098 $3,124 $1,312 $2,832 $3,132 Interest cost on projected benefit obligation 26,110 29,740 7,622 3,628 7,114 5,984 Expected return on assets (39,544 ) (44,192 ) (11,962 ) (5,374 ) (12,124 ) (8,918 ) Amortization of loss 21,872 23,892 5,970 3,230 4,680 5,208 Net pension cost $18,800 $23,538 $4,754 $2,796 $2,502 $5,406 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $13,322 $17,198 $3,964 $1,698 $3,290 $3,914 Interest cost on projected benefit obligation 30,942 34,734 9,004 4,216 8,708 6,986 Expected return on assets (40,052 ) (45,402 ) (12,210 ) (5,450 ) (12,444 ) (9,136 ) Amortization of loss 27,128 29,902 7,448 4,026 6,476 6,528 Net pension cost $31,340 $36,432 $8,206 $4,490 $6,030 $8,292 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 second quarters of 2016 and 2015 , respectively. Entergy recognized $8.5 million and $8.9 million in pension costs for its non-qualified pension plans for the six months ended June 30, 2016 and 2015, respectively. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the second quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost second quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost second quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost six months ended June 30, 2016 $212 $118 $118 $32 $254 Non-qualified pension cost six months ended June 30, 2015 $226 $136 $118 $32 $298 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $16,146 $22,652 Interest cost on accumulated postretirement benefit obligation (APBO) 28,166 35,968 Expected return on assets (20,910 ) (22,688 ) Amortization of prior service credit (22,746 ) (18,640 ) Amortization of loss 9,108 15,786 Net other postretirement benefit cost $9,764 $33,078 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,956 $3,738 $772 $312 $796 $668 Interest cost on APBO 4,648 6,520 1,418 896 2,078 1,058 Expected return on assets (8,928 ) — (2,758 ) (2,308 ) (4,788 ) (1,628 ) Amortization of prior service credit (2,736 ) (3,894 ) (468 ) (372 ) (1,362 ) (786 ) Amortization of loss 2,128 1,464 446 74 1,074 574 Net other postretirement benefit cost ($2,932 ) $7,828 ($590 ) ($1,398 ) ($2,202 ) ($114 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $3,478 $4,948 $1,014 $410 $1,000 $940 Interest cost on APBO 6,260 8,156 1,718 1,304 2,684 1,256 Expected return on assets (9,596 ) — (3,084 ) (2,402 ) (5,176 ) (1,822 ) Amortization of prior service credit (1,220 ) (3,734 ) (458 ) (354 ) (1,362 ) (732 ) Amortization of loss 2,678 3,560 430 236 1,370 600 Net other postretirement benefit cost $1,600 $12,930 ($380 ) ($806 ) ($1,484 ) $242 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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 ) (632 ) (15,177 ) ($12,752 ) $5,675 ($745 ) ($7,822 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (5 ) (1,573 ) ($836 ) $1,215 ($5 ) $374 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($6 ) ($669 ) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($540 ) $15,476 ($226 ) $14,710 Amortization of loss (24,964 ) (4,126 ) (1,262 ) (30,352 ) ($25,504 ) $11,350 ($1,488 ) ($15,642 ) Entergy Louisiana Amortization of prior service credit $— $3,894 $— $3,894 Amortization of loss (1,672 ) (1,464 ) (6 ) (3,142 ) ($1,672 ) $2,430 ($6 ) $752 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($778 ) $12,964 ($215 ) $11,971 Amortization of loss (25,254 ) (8,818 ) (1,104 ) (35,176 ) ($26,032 ) $4,146 ($1,319 ) ($23,205 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $3,734 ($1 ) $3,733 Amortization of loss (1,502 ) (3,558 ) (10 ) (5,070 ) ($1,502 ) $176 ($11 ) ($1,337 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of June 30, 2016 , Entergy had contributed $169.8 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 June 2016 $36,549 $37,319 $8,919 $4,680 $6,999 $8,891 Remaining estimated pension contributions to be made in 2016 $46,282 $46,590 $10,994 $6,014 $8,771 $11,315
Entergy Louisiana [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $71,622 $87,524 Interest cost on projected benefit obligation 130,806 151,388 Expected return on assets (194,732 ) (197,310 ) Amortization of prior service cost 540 780 Amortization of loss 97,648 117,962 Special termination benefit — 76 Net pension costs $105,884 $160,420 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,362 $14,098 $3,124 $1,312 $2,832 $3,132 Interest cost on projected benefit obligation 26,110 29,740 7,622 3,628 7,114 5,984 Expected return on assets (39,544 ) (44,192 ) (11,962 ) (5,374 ) (12,124 ) (8,918 ) Amortization of loss 21,872 23,892 5,970 3,230 4,680 5,208 Net pension cost $18,800 $23,538 $4,754 $2,796 $2,502 $5,406 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $13,322 $17,198 $3,964 $1,698 $3,290 $3,914 Interest cost on projected benefit obligation 30,942 34,734 9,004 4,216 8,708 6,986 Expected return on assets (40,052 ) (45,402 ) (12,210 ) (5,450 ) (12,444 ) (9,136 ) Amortization of loss 27,128 29,902 7,448 4,026 6,476 6,528 Net pension cost $31,340 $36,432 $8,206 $4,490 $6,030 $8,292 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 second quarters of 2016 and 2015 , respectively. Entergy recognized $8.5 million and $8.9 million in pension costs for its non-qualified pension plans for the six months ended June 30, 2016 and 2015, respectively. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the second quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost second quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost second quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost six months ended June 30, 2016 $212 $118 $118 $32 $254 Non-qualified pension cost six months ended June 30, 2015 $226 $136 $118 $32 $298 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $16,146 $22,652 Interest cost on accumulated postretirement benefit obligation (APBO) 28,166 35,968 Expected return on assets (20,910 ) (22,688 ) Amortization of prior service credit (22,746 ) (18,640 ) Amortization of loss 9,108 15,786 Net other postretirement benefit cost $9,764 $33,078 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,956 $3,738 $772 $312 $796 $668 Interest cost on APBO 4,648 6,520 1,418 896 2,078 1,058 Expected return on assets (8,928 ) — (2,758 ) (2,308 ) (4,788 ) (1,628 ) Amortization of prior service credit (2,736 ) (3,894 ) (468 ) (372 ) (1,362 ) (786 ) Amortization of loss 2,128 1,464 446 74 1,074 574 Net other postretirement benefit cost ($2,932 ) $7,828 ($590 ) ($1,398 ) ($2,202 ) ($114 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $3,478 $4,948 $1,014 $410 $1,000 $940 Interest cost on APBO 6,260 8,156 1,718 1,304 2,684 1,256 Expected return on assets (9,596 ) — (3,084 ) (2,402 ) (5,176 ) (1,822 ) Amortization of prior service credit (1,220 ) (3,734 ) (458 ) (354 ) (1,362 ) (732 ) Amortization of loss 2,678 3,560 430 236 1,370 600 Net other postretirement benefit cost $1,600 $12,930 ($380 ) ($806 ) ($1,484 ) $242 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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 ) (632 ) (15,177 ) ($12,752 ) $5,675 ($745 ) ($7,822 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (5 ) (1,573 ) ($836 ) $1,215 ($5 ) $374 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($6 ) ($669 ) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($540 ) $15,476 ($226 ) $14,710 Amortization of loss (24,964 ) (4,126 ) (1,262 ) (30,352 ) ($25,504 ) $11,350 ($1,488 ) ($15,642 ) Entergy Louisiana Amortization of prior service credit $— $3,894 $— $3,894 Amortization of loss (1,672 ) (1,464 ) (6 ) (3,142 ) ($1,672 ) $2,430 ($6 ) $752 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($778 ) $12,964 ($215 ) $11,971 Amortization of loss (25,254 ) (8,818 ) (1,104 ) (35,176 ) ($26,032 ) $4,146 ($1,319 ) ($23,205 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $3,734 ($1 ) $3,733 Amortization of loss (1,502 ) (3,558 ) (10 ) (5,070 ) ($1,502 ) $176 ($11 ) ($1,337 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of June 30, 2016 , Entergy had contributed $169.8 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 June 2016 $36,549 $37,319 $8,919 $4,680 $6,999 $8,891 Remaining estimated pension contributions to be made in 2016 $46,282 $46,590 $10,994 $6,014 $8,771 $11,315
Entergy Mississippi [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $71,622 $87,524 Interest cost on projected benefit obligation 130,806 151,388 Expected return on assets (194,732 ) (197,310 ) Amortization of prior service cost 540 780 Amortization of loss 97,648 117,962 Special termination benefit — 76 Net pension costs $105,884 $160,420 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,362 $14,098 $3,124 $1,312 $2,832 $3,132 Interest cost on projected benefit obligation 26,110 29,740 7,622 3,628 7,114 5,984 Expected return on assets (39,544 ) (44,192 ) (11,962 ) (5,374 ) (12,124 ) (8,918 ) Amortization of loss 21,872 23,892 5,970 3,230 4,680 5,208 Net pension cost $18,800 $23,538 $4,754 $2,796 $2,502 $5,406 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $13,322 $17,198 $3,964 $1,698 $3,290 $3,914 Interest cost on projected benefit obligation 30,942 34,734 9,004 4,216 8,708 6,986 Expected return on assets (40,052 ) (45,402 ) (12,210 ) (5,450 ) (12,444 ) (9,136 ) Amortization of loss 27,128 29,902 7,448 4,026 6,476 6,528 Net pension cost $31,340 $36,432 $8,206 $4,490 $6,030 $8,292 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 second quarters of 2016 and 2015 , respectively. Entergy recognized $8.5 million and $8.9 million in pension costs for its non-qualified pension plans for the six months ended June 30, 2016 and 2015, respectively. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the second quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost second quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost second quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost six months ended June 30, 2016 $212 $118 $118 $32 $254 Non-qualified pension cost six months ended June 30, 2015 $226 $136 $118 $32 $298 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $16,146 $22,652 Interest cost on accumulated postretirement benefit obligation (APBO) 28,166 35,968 Expected return on assets (20,910 ) (22,688 ) Amortization of prior service credit (22,746 ) (18,640 ) Amortization of loss 9,108 15,786 Net other postretirement benefit cost $9,764 $33,078 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,956 $3,738 $772 $312 $796 $668 Interest cost on APBO 4,648 6,520 1,418 896 2,078 1,058 Expected return on assets (8,928 ) — (2,758 ) (2,308 ) (4,788 ) (1,628 ) Amortization of prior service credit (2,736 ) (3,894 ) (468 ) (372 ) (1,362 ) (786 ) Amortization of loss 2,128 1,464 446 74 1,074 574 Net other postretirement benefit cost ($2,932 ) $7,828 ($590 ) ($1,398 ) ($2,202 ) ($114 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $3,478 $4,948 $1,014 $410 $1,000 $940 Interest cost on APBO 6,260 8,156 1,718 1,304 2,684 1,256 Expected return on assets (9,596 ) — (3,084 ) (2,402 ) (5,176 ) (1,822 ) Amortization of prior service credit (1,220 ) (3,734 ) (458 ) (354 ) (1,362 ) (732 ) Amortization of loss 2,678 3,560 430 236 1,370 600 Net other postretirement benefit cost $1,600 $12,930 ($380 ) ($806 ) ($1,484 ) $242 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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 ) (632 ) (15,177 ) ($12,752 ) $5,675 ($745 ) ($7,822 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (5 ) (1,573 ) ($836 ) $1,215 ($5 ) $374 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($6 ) ($669 ) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($540 ) $15,476 ($226 ) $14,710 Amortization of loss (24,964 ) (4,126 ) (1,262 ) (30,352 ) ($25,504 ) $11,350 ($1,488 ) ($15,642 ) Entergy Louisiana Amortization of prior service credit $— $3,894 $— $3,894 Amortization of loss (1,672 ) (1,464 ) (6 ) (3,142 ) ($1,672 ) $2,430 ($6 ) $752 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($778 ) $12,964 ($215 ) $11,971 Amortization of loss (25,254 ) (8,818 ) (1,104 ) (35,176 ) ($26,032 ) $4,146 ($1,319 ) ($23,205 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $3,734 ($1 ) $3,733 Amortization of loss (1,502 ) (3,558 ) (10 ) (5,070 ) ($1,502 ) $176 ($11 ) ($1,337 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of June 30, 2016 , Entergy had contributed $169.8 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 June 2016 $36,549 $37,319 $8,919 $4,680 $6,999 $8,891 Remaining estimated pension contributions to be made in 2016 $46,282 $46,590 $10,994 $6,014 $8,771 $11,315
Entergy New Orleans [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $71,622 $87,524 Interest cost on projected benefit obligation 130,806 151,388 Expected return on assets (194,732 ) (197,310 ) Amortization of prior service cost 540 780 Amortization of loss 97,648 117,962 Special termination benefit — 76 Net pension costs $105,884 $160,420 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,362 $14,098 $3,124 $1,312 $2,832 $3,132 Interest cost on projected benefit obligation 26,110 29,740 7,622 3,628 7,114 5,984 Expected return on assets (39,544 ) (44,192 ) (11,962 ) (5,374 ) (12,124 ) (8,918 ) Amortization of loss 21,872 23,892 5,970 3,230 4,680 5,208 Net pension cost $18,800 $23,538 $4,754 $2,796 $2,502 $5,406 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $13,322 $17,198 $3,964 $1,698 $3,290 $3,914 Interest cost on projected benefit obligation 30,942 34,734 9,004 4,216 8,708 6,986 Expected return on assets (40,052 ) (45,402 ) (12,210 ) (5,450 ) (12,444 ) (9,136 ) Amortization of loss 27,128 29,902 7,448 4,026 6,476 6,528 Net pension cost $31,340 $36,432 $8,206 $4,490 $6,030 $8,292 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 second quarters of 2016 and 2015 , respectively. Entergy recognized $8.5 million and $8.9 million in pension costs for its non-qualified pension plans for the six months ended June 30, 2016 and 2015, respectively. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the second quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost second quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost second quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost six months ended June 30, 2016 $212 $118 $118 $32 $254 Non-qualified pension cost six months ended June 30, 2015 $226 $136 $118 $32 $298 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $16,146 $22,652 Interest cost on accumulated postretirement benefit obligation (APBO) 28,166 35,968 Expected return on assets (20,910 ) (22,688 ) Amortization of prior service credit (22,746 ) (18,640 ) Amortization of loss 9,108 15,786 Net other postretirement benefit cost $9,764 $33,078 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,956 $3,738 $772 $312 $796 $668 Interest cost on APBO 4,648 6,520 1,418 896 2,078 1,058 Expected return on assets (8,928 ) — (2,758 ) (2,308 ) (4,788 ) (1,628 ) Amortization of prior service credit (2,736 ) (3,894 ) (468 ) (372 ) (1,362 ) (786 ) Amortization of loss 2,128 1,464 446 74 1,074 574 Net other postretirement benefit cost ($2,932 ) $7,828 ($590 ) ($1,398 ) ($2,202 ) ($114 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $3,478 $4,948 $1,014 $410 $1,000 $940 Interest cost on APBO 6,260 8,156 1,718 1,304 2,684 1,256 Expected return on assets (9,596 ) — (3,084 ) (2,402 ) (5,176 ) (1,822 ) Amortization of prior service credit (1,220 ) (3,734 ) (458 ) (354 ) (1,362 ) (732 ) Amortization of loss 2,678 3,560 430 236 1,370 600 Net other postretirement benefit cost $1,600 $12,930 ($380 ) ($806 ) ($1,484 ) $242 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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 ) (632 ) (15,177 ) ($12,752 ) $5,675 ($745 ) ($7,822 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (5 ) (1,573 ) ($836 ) $1,215 ($5 ) $374 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($6 ) ($669 ) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($540 ) $15,476 ($226 ) $14,710 Amortization of loss (24,964 ) (4,126 ) (1,262 ) (30,352 ) ($25,504 ) $11,350 ($1,488 ) ($15,642 ) Entergy Louisiana Amortization of prior service credit $— $3,894 $— $3,894 Amortization of loss (1,672 ) (1,464 ) (6 ) (3,142 ) ($1,672 ) $2,430 ($6 ) $752 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($778 ) $12,964 ($215 ) $11,971 Amortization of loss (25,254 ) (8,818 ) (1,104 ) (35,176 ) ($26,032 ) $4,146 ($1,319 ) ($23,205 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $3,734 ($1 ) $3,733 Amortization of loss (1,502 ) (3,558 ) (10 ) (5,070 ) ($1,502 ) $176 ($11 ) ($1,337 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of June 30, 2016 , Entergy had contributed $169.8 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 June 2016 $36,549 $37,319 $8,919 $4,680 $6,999 $8,891 Remaining estimated pension contributions to be made in 2016 $46,282 $46,590 $10,994 $6,014 $8,771 $11,315
Entergy Texas [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $71,622 $87,524 Interest cost on projected benefit obligation 130,806 151,388 Expected return on assets (194,732 ) (197,310 ) Amortization of prior service cost 540 780 Amortization of loss 97,648 117,962 Special termination benefit — 76 Net pension costs $105,884 $160,420 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,362 $14,098 $3,124 $1,312 $2,832 $3,132 Interest cost on projected benefit obligation 26,110 29,740 7,622 3,628 7,114 5,984 Expected return on assets (39,544 ) (44,192 ) (11,962 ) (5,374 ) (12,124 ) (8,918 ) Amortization of loss 21,872 23,892 5,970 3,230 4,680 5,208 Net pension cost $18,800 $23,538 $4,754 $2,796 $2,502 $5,406 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $13,322 $17,198 $3,964 $1,698 $3,290 $3,914 Interest cost on projected benefit obligation 30,942 34,734 9,004 4,216 8,708 6,986 Expected return on assets (40,052 ) (45,402 ) (12,210 ) (5,450 ) (12,444 ) (9,136 ) Amortization of loss 27,128 29,902 7,448 4,026 6,476 6,528 Net pension cost $31,340 $36,432 $8,206 $4,490 $6,030 $8,292 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 second quarters of 2016 and 2015 , respectively. Entergy recognized $8.5 million and $8.9 million in pension costs for its non-qualified pension plans for the six months ended June 30, 2016 and 2015, respectively. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the second quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost second quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost second quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost six months ended June 30, 2016 $212 $118 $118 $32 $254 Non-qualified pension cost six months ended June 30, 2015 $226 $136 $118 $32 $298 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $16,146 $22,652 Interest cost on accumulated postretirement benefit obligation (APBO) 28,166 35,968 Expected return on assets (20,910 ) (22,688 ) Amortization of prior service credit (22,746 ) (18,640 ) Amortization of loss 9,108 15,786 Net other postretirement benefit cost $9,764 $33,078 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,956 $3,738 $772 $312 $796 $668 Interest cost on APBO 4,648 6,520 1,418 896 2,078 1,058 Expected return on assets (8,928 ) — (2,758 ) (2,308 ) (4,788 ) (1,628 ) Amortization of prior service credit (2,736 ) (3,894 ) (468 ) (372 ) (1,362 ) (786 ) Amortization of loss 2,128 1,464 446 74 1,074 574 Net other postretirement benefit cost ($2,932 ) $7,828 ($590 ) ($1,398 ) ($2,202 ) ($114 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $3,478 $4,948 $1,014 $410 $1,000 $940 Interest cost on APBO 6,260 8,156 1,718 1,304 2,684 1,256 Expected return on assets (9,596 ) — (3,084 ) (2,402 ) (5,176 ) (1,822 ) Amortization of prior service credit (1,220 ) (3,734 ) (458 ) (354 ) (1,362 ) (732 ) Amortization of loss 2,678 3,560 430 236 1,370 600 Net other postretirement benefit cost $1,600 $12,930 ($380 ) ($806 ) ($1,484 ) $242 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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 ) (632 ) (15,177 ) ($12,752 ) $5,675 ($745 ) ($7,822 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (5 ) (1,573 ) ($836 ) $1,215 ($5 ) $374 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($6 ) ($669 ) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($540 ) $15,476 ($226 ) $14,710 Amortization of loss (24,964 ) (4,126 ) (1,262 ) (30,352 ) ($25,504 ) $11,350 ($1,488 ) ($15,642 ) Entergy Louisiana Amortization of prior service credit $— $3,894 $— $3,894 Amortization of loss (1,672 ) (1,464 ) (6 ) (3,142 ) ($1,672 ) $2,430 ($6 ) $752 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($778 ) $12,964 ($215 ) $11,971 Amortization of loss (25,254 ) (8,818 ) (1,104 ) (35,176 ) ($26,032 ) $4,146 ($1,319 ) ($23,205 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $3,734 ($1 ) $3,733 Amortization of loss (1,502 ) (3,558 ) (10 ) (5,070 ) ($1,502 ) $176 ($11 ) ($1,337 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of June 30, 2016 , Entergy had contributed $169.8 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 June 2016 $36,549 $37,319 $8,919 $4,680 $6,999 $8,891 Remaining estimated pension contributions to be made in 2016 $46,282 $46,590 $10,994 $6,014 $8,771 $11,315
System Energy [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $71,622 $87,524 Interest cost on projected benefit obligation 130,806 151,388 Expected return on assets (194,732 ) (197,310 ) Amortization of prior service cost 540 780 Amortization of loss 97,648 117,962 Special termination benefit — 76 Net pension costs $105,884 $160,420 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,362 $14,098 $3,124 $1,312 $2,832 $3,132 Interest cost on projected benefit obligation 26,110 29,740 7,622 3,628 7,114 5,984 Expected return on assets (39,544 ) (44,192 ) (11,962 ) (5,374 ) (12,124 ) (8,918 ) Amortization of loss 21,872 23,892 5,970 3,230 4,680 5,208 Net pension cost $18,800 $23,538 $4,754 $2,796 $2,502 $5,406 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $13,322 $17,198 $3,964 $1,698 $3,290 $3,914 Interest cost on projected benefit obligation 30,942 34,734 9,004 4,216 8,708 6,986 Expected return on assets (40,052 ) (45,402 ) (12,210 ) (5,450 ) (12,444 ) (9,136 ) Amortization of loss 27,128 29,902 7,448 4,026 6,476 6,528 Net pension cost $31,340 $36,432 $8,206 $4,490 $6,030 $8,292 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 second quarters of 2016 and 2015 , respectively. Entergy recognized $8.5 million and $8.9 million in pension costs for its non-qualified pension plans for the six months ended June 30, 2016 and 2015, respectively. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the second quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost second quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost second quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost six months ended June 30, 2016 $212 $118 $118 $32 $254 Non-qualified pension cost six months ended June 30, 2015 $226 $136 $118 $32 $298 Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $16,146 $22,652 Interest cost on accumulated postretirement benefit obligation (APBO) 28,166 35,968 Expected return on assets (20,910 ) (22,688 ) Amortization of prior service credit (22,746 ) (18,640 ) Amortization of loss 9,108 15,786 Net other postretirement benefit cost $9,764 $33,078 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,956 $3,738 $772 $312 $796 $668 Interest cost on APBO 4,648 6,520 1,418 896 2,078 1,058 Expected return on assets (8,928 ) — (2,758 ) (2,308 ) (4,788 ) (1,628 ) Amortization of prior service credit (2,736 ) (3,894 ) (468 ) (372 ) (1,362 ) (786 ) Amortization of loss 2,128 1,464 446 74 1,074 574 Net other postretirement benefit cost ($2,932 ) $7,828 ($590 ) ($1,398 ) ($2,202 ) ($114 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $3,478 $4,948 $1,014 $410 $1,000 $940 Interest cost on APBO 6,260 8,156 1,718 1,304 2,684 1,256 Expected return on assets (9,596 ) — (3,084 ) (2,402 ) (5,176 ) (1,822 ) Amortization of prior service credit (1,220 ) (3,734 ) (458 ) (354 ) (1,362 ) (732 ) Amortization of loss 2,678 3,560 430 236 1,370 600 Net other postretirement benefit cost $1,600 $12,930 ($380 ) ($806 ) ($1,484 ) $242 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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 ) (632 ) (15,177 ) ($12,752 ) $5,675 ($745 ) ($7,822 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (5 ) (1,573 ) ($836 ) $1,215 ($5 ) $374 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($6 ) ($669 ) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($540 ) $15,476 ($226 ) $14,710 Amortization of loss (24,964 ) (4,126 ) (1,262 ) (30,352 ) ($25,504 ) $11,350 ($1,488 ) ($15,642 ) Entergy Louisiana Amortization of prior service credit $— $3,894 $— $3,894 Amortization of loss (1,672 ) (1,464 ) (6 ) (3,142 ) ($1,672 ) $2,430 ($6 ) $752 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($778 ) $12,964 ($215 ) $11,971 Amortization of loss (25,254 ) (8,818 ) (1,104 ) (35,176 ) ($26,032 ) $4,146 ($1,319 ) ($23,205 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $3,734 ($1 ) $3,733 Amortization of loss (1,502 ) (3,558 ) (10 ) (5,070 ) ($1,502 ) $176 ($11 ) ($1,337 ) Employer Contributions Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of June 30, 2016 , Entergy had contributed $169.8 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 June 2016 $36,549 $37,319 $8,919 $4,680 $6,999 $8,891 Remaining estimated pension contributions to be made in 2016 $46,282 $46,590 $10,994 $6,014 $8,771 $11,315

Business Segment Information

Business Segment Information	6 Months Ended
	Jun. 30, 2016
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of June 30, 2016 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the second quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,118,478 $344,110 $— ($26 ) $2,462,562 Income taxes ($3,785 ) ($235,055 ) ($10,133 ) $— ($248,973 ) Consolidated net income (loss) $380,317 $250,874 ($26,703 ) ($31,898 ) $572,590 2015 Operating revenues $2,273,945 $439,306 $— ($20 ) $2,713,231 Income taxes $117,798 ($3,300 ) ($14,717 ) $— $99,781 Consolidated net income (loss) $204,035 ($3,545 ) ($14,870 ) ($31,898 ) $153,722 Entergy’s segment financial information for the six months ended June 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $4,206,272 $866,189 $— ($46 ) $5,072,415 Income taxes $104,051 ($182,741 ) ($30,337 ) $— ($109,027 ) Consolidated net income (loss) $579,968 $330,430 ($38,769 ) ($63,797 ) $807,832 Total assets as of June 30, 2016 $39,841,100 $7,913,442 $1,211,715 ($3,089,215 ) $45,877,042 2015 Operating revenues $4,551,455 $1,081,896 $— ($30 ) $5,633,321 Income taxes $209,048 $66,891 ($25,687 ) $— $250,252 Consolidated net income (loss) $431,786 $119,887 ($31,224 ) ($63,798 ) $456,651 Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
Entergy Arkansas [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of June 30, 2016 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the second quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,118,478 $344,110 $— ($26 ) $2,462,562 Income taxes ($3,785 ) ($235,055 ) ($10,133 ) $— ($248,973 ) Consolidated net income (loss) $380,317 $250,874 ($26,703 ) ($31,898 ) $572,590 2015 Operating revenues $2,273,945 $439,306 $— ($20 ) $2,713,231 Income taxes $117,798 ($3,300 ) ($14,717 ) $— $99,781 Consolidated net income (loss) $204,035 ($3,545 ) ($14,870 ) ($31,898 ) $153,722 Entergy’s segment financial information for the six months ended June 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $4,206,272 $866,189 $— ($46 ) $5,072,415 Income taxes $104,051 ($182,741 ) ($30,337 ) $— ($109,027 ) Consolidated net income (loss) $579,968 $330,430 ($38,769 ) ($63,797 ) $807,832 Total assets as of June 30, 2016 $39,841,100 $7,913,442 $1,211,715 ($3,089,215 ) $45,877,042 2015 Operating revenues $4,551,455 $1,081,896 $— ($30 ) $5,633,321 Income taxes $209,048 $66,891 ($25,687 ) $— $250,252 Consolidated net income (loss) $431,786 $119,887 ($31,224 ) ($63,798 ) $456,651 Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
Entergy Louisiana [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of June 30, 2016 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the second quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,118,478 $344,110 $— ($26 ) $2,462,562 Income taxes ($3,785 ) ($235,055 ) ($10,133 ) $— ($248,973 ) Consolidated net income (loss) $380,317 $250,874 ($26,703 ) ($31,898 ) $572,590 2015 Operating revenues $2,273,945 $439,306 $— ($20 ) $2,713,231 Income taxes $117,798 ($3,300 ) ($14,717 ) $— $99,781 Consolidated net income (loss) $204,035 ($3,545 ) ($14,870 ) ($31,898 ) $153,722 Entergy’s segment financial information for the six months ended June 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $4,206,272 $866,189 $— ($46 ) $5,072,415 Income taxes $104,051 ($182,741 ) ($30,337 ) $— ($109,027 ) Consolidated net income (loss) $579,968 $330,430 ($38,769 ) ($63,797 ) $807,832 Total assets as of June 30, 2016 $39,841,100 $7,913,442 $1,211,715 ($3,089,215 ) $45,877,042 2015 Operating revenues $4,551,455 $1,081,896 $— ($30 ) $5,633,321 Income taxes $209,048 $66,891 ($25,687 ) $— $250,252 Consolidated net income (loss) $431,786 $119,887 ($31,224 ) ($63,798 ) $456,651 Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
Entergy Mississippi [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of June 30, 2016 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the second quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,118,478 $344,110 $— ($26 ) $2,462,562 Income taxes ($3,785 ) ($235,055 ) ($10,133 ) $— ($248,973 ) Consolidated net income (loss) $380,317 $250,874 ($26,703 ) ($31,898 ) $572,590 2015 Operating revenues $2,273,945 $439,306 $— ($20 ) $2,713,231 Income taxes $117,798 ($3,300 ) ($14,717 ) $— $99,781 Consolidated net income (loss) $204,035 ($3,545 ) ($14,870 ) ($31,898 ) $153,722 Entergy’s segment financial information for the six months ended June 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $4,206,272 $866,189 $— ($46 ) $5,072,415 Income taxes $104,051 ($182,741 ) ($30,337 ) $— ($109,027 ) Consolidated net income (loss) $579,968 $330,430 ($38,769 ) ($63,797 ) $807,832 Total assets as of June 30, 2016 $39,841,100 $7,913,442 $1,211,715 ($3,089,215 ) $45,877,042 2015 Operating revenues $4,551,455 $1,081,896 $— ($30 ) $5,633,321 Income taxes $209,048 $66,891 ($25,687 ) $— $250,252 Consolidated net income (loss) $431,786 $119,887 ($31,224 ) ($63,798 ) $456,651 Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
Entergy New Orleans [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of June 30, 2016 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the second quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,118,478 $344,110 $— ($26 ) $2,462,562 Income taxes ($3,785 ) ($235,055 ) ($10,133 ) $— ($248,973 ) Consolidated net income (loss) $380,317 $250,874 ($26,703 ) ($31,898 ) $572,590 2015 Operating revenues $2,273,945 $439,306 $— ($20 ) $2,713,231 Income taxes $117,798 ($3,300 ) ($14,717 ) $— $99,781 Consolidated net income (loss) $204,035 ($3,545 ) ($14,870 ) ($31,898 ) $153,722 Entergy’s segment financial information for the six months ended June 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $4,206,272 $866,189 $— ($46 ) $5,072,415 Income taxes $104,051 ($182,741 ) ($30,337 ) $— ($109,027 ) Consolidated net income (loss) $579,968 $330,430 ($38,769 ) ($63,797 ) $807,832 Total assets as of June 30, 2016 $39,841,100 $7,913,442 $1,211,715 ($3,089,215 ) $45,877,042 2015 Operating revenues $4,551,455 $1,081,896 $— ($30 ) $5,633,321 Income taxes $209,048 $66,891 ($25,687 ) $— $250,252 Consolidated net income (loss) $431,786 $119,887 ($31,224 ) ($63,798 ) $456,651 Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
Entergy Texas [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of June 30, 2016 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the second quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,118,478 $344,110 $— ($26 ) $2,462,562 Income taxes ($3,785 ) ($235,055 ) ($10,133 ) $— ($248,973 ) Consolidated net income (loss) $380,317 $250,874 ($26,703 ) ($31,898 ) $572,590 2015 Operating revenues $2,273,945 $439,306 $— ($20 ) $2,713,231 Income taxes $117,798 ($3,300 ) ($14,717 ) $— $99,781 Consolidated net income (loss) $204,035 ($3,545 ) ($14,870 ) ($31,898 ) $153,722 Entergy’s segment financial information for the six months ended June 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $4,206,272 $866,189 $— ($46 ) $5,072,415 Income taxes $104,051 ($182,741 ) ($30,337 ) $— ($109,027 ) Consolidated net income (loss) $579,968 $330,430 ($38,769 ) ($63,797 ) $807,832 Total assets as of June 30, 2016 $39,841,100 $7,913,442 $1,211,715 ($3,089,215 ) $45,877,042 2015 Operating revenues $4,551,455 $1,081,896 $— ($30 ) $5,633,321 Income taxes $209,048 $66,891 ($25,687 ) $— $250,252 Consolidated net income (loss) $431,786 $119,887 ($31,224 ) ($63,798 ) $456,651 Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
System Energy [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of June 30, 2016 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the second quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,118,478 $344,110 $— ($26 ) $2,462,562 Income taxes ($3,785 ) ($235,055 ) ($10,133 ) $— ($248,973 ) Consolidated net income (loss) $380,317 $250,874 ($26,703 ) ($31,898 ) $572,590 2015 Operating revenues $2,273,945 $439,306 $— ($20 ) $2,713,231 Income taxes $117,798 ($3,300 ) ($14,717 ) $— $99,781 Consolidated net income (loss) $204,035 ($3,545 ) ($14,870 ) ($31,898 ) $153,722 Entergy’s segment financial information for the six months ended June 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $4,206,272 $866,189 $— ($46 ) $5,072,415 Income taxes $104,051 ($182,741 ) ($30,337 ) $— ($109,027 ) Consolidated net income (loss) $579,968 $330,430 ($38,769 ) ($63,797 ) $807,832 Total assets as of June 30, 2016 $39,841,100 $7,913,442 $1,211,715 ($3,089,215 ) $45,877,042 2015 Operating revenues $4,551,455 $1,081,896 $— ($30 ) $5,633,321 Income taxes $209,048 $66,891 ($25,687 ) $— $250,252 Consolidated net income (loss) $431,786 $119,887 ($31,224 ) ($63,798 ) $456,651 Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

Risk Management And Fair Values

Risk Management And Fair Values	6 Months Ended
	Jun. 30, 2016
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at June 30, 2016 is approximately 2 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 87% 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 18 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 June 30, 2016 , derivative contracts with four counterparties were in a liability position (approximately $7 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and letters of credit in the amount of $23 million were required to be posted by its counterparties to the Entergy subsidiary as of June 30, 2016. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). As of December 31, 2015, $9 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $68 million was required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate guarantee is typically ignored and Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of short-term natural gas swaps that financially settle against NYMEX futures. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of June 30, 2016 is 32,588,000 MMBtu for Entergy, including 26,370,000 MMBtu for Entergy Louisiana, 5,950,000 MMBtu for Entergy Mississippi, and 268,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests. During the second quarter 2016, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2016 through May 31, 2017. FTRs are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records FTRs at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on FTRs held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on FTRs. The total volume of FTRs outstanding as of June 30, 2016 is 103,995 GWh for Entergy, including 23,627 GWh for Entergy Arkansas, 44,556 GWh for Entergy Louisiana, 16,903 GWh for Entergy Mississippi, 5,064 GWh for Entergy New Orleans, and 13,301 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 June 30, 2016 , letters of credit posted with MISO covered the FTR exposure for Entergy Texas. 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 June 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($9) $41 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $7 ($7) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $7 ($5) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($22) $28 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $8 $— $8 Entergy Wholesale Commodities Natural gas swaps Prepayments and other $16 $— $16 Utility FTRs Prepayments and other $47 ($1) $46 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $31 ($24) $7 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($1) $2 Entergy Wholesale Commodities 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 $1 million posted as of June 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $1 million posted and $23 million held as of June 30, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 2015 Electricity swaps and options $137 Competitive businesses operating revenues $78 (a) Before taxes of $16 million and $27 million for the three months ended June 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 2015 Electricity swaps and options $105 Competitive businesses operating revenues $91 (a) Before taxes of $70 million and $32 million for the six months ended June 30, 2016 and 2015, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended June 30, 2016 and 2015 was ($3) million and $2 million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2016 and 2015 was ($0.3) million and $1 million , respectively. Based on market prices as of June 30, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $53 million . Approximately $51 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 June 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($6) FTRs $— Purchased power expense (b) $38 Electricity swaps and options de-designated as hedged items ($10) Competitive business operating revenues ($6) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $3 FTRs $— Purchased power expense (b) $46 Electricity swaps and options de-designated as hedged items ($3) Competitive business operating revenues ($5) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) FTRs $— Purchased power expense (b) $59 Electricity swaps and options de-designated as hedged items $15 Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) FTRs $— Purchased power expense (b) $79 Electricity swaps and options de-designated as hedged items $1 Competitive business operating revenues ($39) (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 June 30, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $12.8 Entergy Louisiana Natural gas swaps Prepayments and other $2.7 Entergy Mississippi FTRs Prepayments and other $14.0 Entergy Arkansas FTRs Prepayments and other $16.2 Entergy Louisiana FTRs Prepayments and other $5.6 Entergy Mississippi FTRs Prepayments and other $2.0 Entergy New Orleans FTRs Prepayments and other $8.0 Entergy Texas 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 $1.4 million posted by Entergy Texas as of June 30, 2016. No cash collateral was required to be posted as of June 30, 2016 and December 31, 2015, respectively. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy Mississippi FTRs Purchased power expense $5.5 (b) Entergy Arkansas FTRs Purchased power expense $21.6 (b) Entergy Louisiana FTRs Purchased power expense $3.6 (b) Entergy Mississippi FTRs Purchased power expense $1.4 (b) Entergy New Orleans FTRs Purchased power expense $5.4 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $2.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.6 (a) Entergy Mississippi FTRs Purchased power expense $19.6 (b) Entergy Arkansas FTRs Purchased power expense $17.3 (b) Entergy Louisiana FTRs Purchased power expense $3.9 (b) Entergy Mississippi FTRs Purchased power expense $4.5 (b) Entergy New Orleans FTRs Purchased power expense $1.2 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($24.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.0) (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 $13.3 (b) Entergy Arkansas FTRs Purchased power expense $32.1 (b) Entergy Louisiana FTRs Purchased power expense $4.4 (b) Entergy Mississippi FTRs Purchased power expense $1.9 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.5) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.4) (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 $34.7 (b) Entergy Arkansas FTRs Purchased power expense $31.7 (b) Entergy Louisiana FTRs Purchased power expense $7.2 (b) Entergy Mississippi FTRs Purchased power expense $6.0 (b) Entergy New Orleans FTRs Purchased power expense ($0.2) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of FTRs for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. Effective first quarter 2016, Entergy retrospectively adopted ASU 2015-07, which simplifies the disclosure for fair value investments by removing the requirement to categorize within the fair value hierarchy investment for which fair value is measured using the net asset value per share as a practical expedient. For all periods presented the common trust funds have not been assigned a level and are presented within the fair value tables only as a reconciling item to the total fair value of investments. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: - quoted prices for similar assets or liabilities in active markets; - quoted prices for identical assets or liabilities in inactive markets; - inputs other than quoted prices that are observable for the asset or liability; or - inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of FTRs and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options. The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available, and uses multiple sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In
Entergy Arkansas [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at June 30, 2016 is approximately 2 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 87% 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 18 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 June 30, 2016 , derivative contracts with four counterparties were in a liability position (approximately $7 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and letters of credit in the amount of $23 million were required to be posted by its counterparties to the Entergy subsidiary as of June 30, 2016. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). As of December 31, 2015, $9 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $68 million was required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate guarantee is typically ignored and Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of short-term natural gas swaps that financially settle against NYMEX futures. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of June 30, 2016 is 32,588,000 MMBtu for Entergy, including 26,370,000 MMBtu for Entergy Louisiana, 5,950,000 MMBtu for Entergy Mississippi, and 268,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests. During the second quarter 2016, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2016 through May 31, 2017. FTRs are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records FTRs at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on FTRs held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on FTRs. The total volume of FTRs outstanding as of June 30, 2016 is 103,995 GWh for Entergy, including 23,627 GWh for Entergy Arkansas, 44,556 GWh for Entergy Louisiana, 16,903 GWh for Entergy Mississippi, 5,064 GWh for Entergy New Orleans, and 13,301 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 June 30, 2016 , letters of credit posted with MISO covered the FTR exposure for Entergy Texas. 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 June 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($9) $41 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $7 ($7) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $7 ($5) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($22) $28 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $8 $— $8 Entergy Wholesale Commodities Natural gas swaps Prepayments and other $16 $— $16 Utility FTRs Prepayments and other $47 ($1) $46 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $31 ($24) $7 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($1) $2 Entergy Wholesale Commodities 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 $1 million posted as of June 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $1 million posted and $23 million held as of June 30, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 2015 Electricity swaps and options $137 Competitive businesses operating revenues $78 (a) Before taxes of $16 million and $27 million for the three months ended June 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 2015 Electricity swaps and options $105 Competitive businesses operating revenues $91 (a) Before taxes of $70 million and $32 million for the six months ended June 30, 2016 and 2015, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended June 30, 2016 and 2015 was ($3) million and $2 million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2016 and 2015 was ($0.3) million and $1 million , respectively. Based on market prices as of June 30, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $53 million . Approximately $51 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 June 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($6) FTRs $— Purchased power expense (b) $38 Electricity swaps and options de-designated as hedged items ($10) Competitive business operating revenues ($6) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $3 FTRs $— Purchased power expense (b) $46 Electricity swaps and options de-designated as hedged items ($3) Competitive business operating revenues ($5) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) FTRs $— Purchased power expense (b) $59 Electricity swaps and options de-designated as hedged items $15 Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) FTRs $— Purchased power expense (b) $79 Electricity swaps and options de-designated as hedged items $1 Competitive business operating revenues ($39) (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 June 30, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $12.8 Entergy Louisiana Natural gas swaps Prepayments and other $2.7 Entergy Mississippi FTRs Prepayments and other $14.0 Entergy Arkansas FTRs Prepayments and other $16.2 Entergy Louisiana FTRs Prepayments and other $5.6 Entergy Mississippi FTRs Prepayments and other $2.0 Entergy New Orleans FTRs Prepayments and other $8.0 Entergy Texas 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 $1.4 million posted by Entergy Texas as of June 30, 2016. No cash collateral was required to be posted as of June 30, 2016 and December 31, 2015, respectively. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy Mississippi FTRs Purchased power expense $5.5 (b) Entergy Arkansas FTRs Purchased power expense $21.6 (b) Entergy Louisiana FTRs Purchased power expense $3.6 (b) Entergy Mississippi FTRs Purchased power expense $1.4 (b) Entergy New Orleans FTRs Purchased power expense $5.4 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $2.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.6 (a) Entergy Mississippi FTRs Purchased power expense $19.6 (b) Entergy Arkansas FTRs Purchased power expense $17.3 (b) Entergy Louisiana FTRs Purchased power expense $3.9 (b) Entergy Mississippi FTRs Purchased power expense $4.5 (b) Entergy New Orleans FTRs Purchased power expense $1.2 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($24.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.0) (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 $13.3 (b) Entergy Arkansas FTRs Purchased power expense $32.1 (b) Entergy Louisiana FTRs Purchased power expense $4.4 (b) Entergy Mississippi FTRs Purchased power expense $1.9 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.5) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.4) (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 $34.7 (b) Entergy Arkansas FTRs Purchased power expense $31.7 (b) Entergy Louisiana FTRs Purchased power expense $7.2 (b) Entergy Mississippi FTRs Purchased power expense $6.0 (b) Entergy New Orleans FTRs Purchased power expense ($0.2) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of FTRs for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. Effective first quarter 2016, Entergy retrospectively adopted ASU 2015-07, which simplifies the disclosure for fair value investments by removing the requirement to categorize within the fair value hierarchy investment for which fair value is measured using the net asset value per share as a practical expedient. For all periods presented the common trust funds have not been assigned a level and are presented within the fair value tables only as a reconciling item to the total fair value of investments. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: - quoted prices for similar assets or liabilities in active markets; - quoted prices for identical assets or liabilities in inactive markets; - inputs other than quoted prices that are observable for the asset or liability; or - inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of FTRs and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options. The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available, and uses multiple sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In
Entergy Louisiana [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at June 30, 2016 is approximately 2 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 87% 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 18 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 June 30, 2016 , derivative contracts with four counterparties were in a liability position (approximately $7 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and letters of credit in the amount of $23 million were required to be posted by its counterparties to the Entergy subsidiary as of June 30, 2016. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). As of December 31, 2015, $9 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $68 million was required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate guarantee is typically ignored and Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of short-term natural gas swaps that financially settle against NYMEX futures. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of June 30, 2016 is 32,588,000 MMBtu for Entergy, including 26,370,000 MMBtu for Entergy Louisiana, 5,950,000 MMBtu for Entergy Mississippi, and 268,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests. During the second quarter 2016, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2016 through May 31, 2017. FTRs are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records FTRs at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on FTRs held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on FTRs. The total volume of FTRs outstanding as of June 30, 2016 is 103,995 GWh for Entergy, including 23,627 GWh for Entergy Arkansas, 44,556 GWh for Entergy Louisiana, 16,903 GWh for Entergy Mississippi, 5,064 GWh for Entergy New Orleans, and 13,301 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 June 30, 2016 , letters of credit posted with MISO covered the FTR exposure for Entergy Texas. 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 June 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($9) $41 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $7 ($7) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $7 ($5) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($22) $28 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $8 $— $8 Entergy Wholesale Commodities Natural gas swaps Prepayments and other $16 $— $16 Utility FTRs Prepayments and other $47 ($1) $46 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $31 ($24) $7 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($1) $2 Entergy Wholesale Commodities 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 $1 million posted as of June 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $1 million posted and $23 million held as of June 30, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 2015 Electricity swaps and options $137 Competitive businesses operating revenues $78 (a) Before taxes of $16 million and $27 million for the three months ended June 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 2015 Electricity swaps and options $105 Competitive businesses operating revenues $91 (a) Before taxes of $70 million and $32 million for the six months ended June 30, 2016 and 2015, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended June 30, 2016 and 2015 was ($3) million and $2 million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2016 and 2015 was ($0.3) million and $1 million , respectively. Based on market prices as of June 30, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $53 million . Approximately $51 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 June 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($6) FTRs $— Purchased power expense (b) $38 Electricity swaps and options de-designated as hedged items ($10) Competitive business operating revenues ($6) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $3 FTRs $— Purchased power expense (b) $46 Electricity swaps and options de-designated as hedged items ($3) Competitive business operating revenues ($5) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) FTRs $— Purchased power expense (b) $59 Electricity swaps and options de-designated as hedged items $15 Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) FTRs $— Purchased power expense (b) $79 Electricity swaps and options de-designated as hedged items $1 Competitive business operating revenues ($39) (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 June 30, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $12.8 Entergy Louisiana Natural gas swaps Prepayments and other $2.7 Entergy Mississippi FTRs Prepayments and other $14.0 Entergy Arkansas FTRs Prepayments and other $16.2 Entergy Louisiana FTRs Prepayments and other $5.6 Entergy Mississippi FTRs Prepayments and other $2.0 Entergy New Orleans FTRs Prepayments and other $8.0 Entergy Texas 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 $1.4 million posted by Entergy Texas as of June 30, 2016. No cash collateral was required to be posted as of June 30, 2016 and December 31, 2015, respectively. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy Mississippi FTRs Purchased power expense $5.5 (b) Entergy Arkansas FTRs Purchased power expense $21.6 (b) Entergy Louisiana FTRs Purchased power expense $3.6 (b) Entergy Mississippi FTRs Purchased power expense $1.4 (b) Entergy New Orleans FTRs Purchased power expense $5.4 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $2.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.6 (a) Entergy Mississippi FTRs Purchased power expense $19.6 (b) Entergy Arkansas FTRs Purchased power expense $17.3 (b) Entergy Louisiana FTRs Purchased power expense $3.9 (b) Entergy Mississippi FTRs Purchased power expense $4.5 (b) Entergy New Orleans FTRs Purchased power expense $1.2 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($24.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.0) (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 $13.3 (b) Entergy Arkansas FTRs Purchased power expense $32.1 (b) Entergy Louisiana FTRs Purchased power expense $4.4 (b) Entergy Mississippi FTRs Purchased power expense $1.9 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.5) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.4) (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 $34.7 (b) Entergy Arkansas FTRs Purchased power expense $31.7 (b) Entergy Louisiana FTRs Purchased power expense $7.2 (b) Entergy Mississippi FTRs Purchased power expense $6.0 (b) Entergy New Orleans FTRs Purchased power expense ($0.2) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of FTRs for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. Effective first quarter 2016, Entergy retrospectively adopted ASU 2015-07, which simplifies the disclosure for fair value investments by removing the requirement to categorize within the fair value hierarchy investment for which fair value is measured using the net asset value per share as a practical expedient. For all periods presented the common trust funds have not been assigned a level and are presented within the fair value tables only as a reconciling item to the total fair value of investments. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: - quoted prices for similar assets or liabilities in active markets; - quoted prices for identical assets or liabilities in inactive markets; - inputs other than quoted prices that are observable for the asset or liability; or - inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of FTRs and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options. The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available, and uses multiple sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In
Entergy Mississippi [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at June 30, 2016 is approximately 2 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 87% 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 18 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 June 30, 2016 , derivative contracts with four counterparties were in a liability position (approximately $7 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and letters of credit in the amount of $23 million were required to be posted by its counterparties to the Entergy subsidiary as of June 30, 2016. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). As of December 31, 2015, $9 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $68 million was required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate guarantee is typically ignored and Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of short-term natural gas swaps that financially settle against NYMEX futures. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of June 30, 2016 is 32,588,000 MMBtu for Entergy, including 26,370,000 MMBtu for Entergy Louisiana, 5,950,000 MMBtu for Entergy Mississippi, and 268,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests. During the second quarter 2016, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2016 through May 31, 2017. FTRs are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records FTRs at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on FTRs held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on FTRs. The total volume of FTRs outstanding as of June 30, 2016 is 103,995 GWh for Entergy, including 23,627 GWh for Entergy Arkansas, 44,556 GWh for Entergy Louisiana, 16,903 GWh for Entergy Mississippi, 5,064 GWh for Entergy New Orleans, and 13,301 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 June 30, 2016 , letters of credit posted with MISO covered the FTR exposure for Entergy Texas. 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 June 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($9) $41 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $7 ($7) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $7 ($5) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($22) $28 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $8 $— $8 Entergy Wholesale Commodities Natural gas swaps Prepayments and other $16 $— $16 Utility FTRs Prepayments and other $47 ($1) $46 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $31 ($24) $7 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($1) $2 Entergy Wholesale Commodities 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 $1 million posted as of June 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $1 million posted and $23 million held as of June 30, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 2015 Electricity swaps and options $137 Competitive businesses operating revenues $78 (a) Before taxes of $16 million and $27 million for the three months ended June 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 2015 Electricity swaps and options $105 Competitive businesses operating revenues $91 (a) Before taxes of $70 million and $32 million for the six months ended June 30, 2016 and 2015, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended June 30, 2016 and 2015 was ($3) million and $2 million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2016 and 2015 was ($0.3) million and $1 million , respectively. Based on market prices as of June 30, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $53 million . Approximately $51 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 June 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($6) FTRs $— Purchased power expense (b) $38 Electricity swaps and options de-designated as hedged items ($10) Competitive business operating revenues ($6) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $3 FTRs $— Purchased power expense (b) $46 Electricity swaps and options de-designated as hedged items ($3) Competitive business operating revenues ($5) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) FTRs $— Purchased power expense (b) $59 Electricity swaps and options de-designated as hedged items $15 Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) FTRs $— Purchased power expense (b) $79 Electricity swaps and options de-designated as hedged items $1 Competitive business operating revenues ($39) (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 June 30, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $12.8 Entergy Louisiana Natural gas swaps Prepayments and other $2.7 Entergy Mississippi FTRs Prepayments and other $14.0 Entergy Arkansas FTRs Prepayments and other $16.2 Entergy Louisiana FTRs Prepayments and other $5.6 Entergy Mississippi FTRs Prepayments and other $2.0 Entergy New Orleans FTRs Prepayments and other $8.0 Entergy Texas 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 $1.4 million posted by Entergy Texas as of June 30, 2016. No cash collateral was required to be posted as of June 30, 2016 and December 31, 2015, respectively. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy Mississippi FTRs Purchased power expense $5.5 (b) Entergy Arkansas FTRs Purchased power expense $21.6 (b) Entergy Louisiana FTRs Purchased power expense $3.6 (b) Entergy Mississippi FTRs Purchased power expense $1.4 (b) Entergy New Orleans FTRs Purchased power expense $5.4 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $2.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.6 (a) Entergy Mississippi FTRs Purchased power expense $19.6 (b) Entergy Arkansas FTRs Purchased power expense $17.3 (b) Entergy Louisiana FTRs Purchased power expense $3.9 (b) Entergy Mississippi FTRs Purchased power expense $4.5 (b) Entergy New Orleans FTRs Purchased power expense $1.2 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($24.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.0) (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 $13.3 (b) Entergy Arkansas FTRs Purchased power expense $32.1 (b) Entergy Louisiana FTRs Purchased power expense $4.4 (b) Entergy Mississippi FTRs Purchased power expense $1.9 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.5) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.4) (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 $34.7 (b) Entergy Arkansas FTRs Purchased power expense $31.7 (b) Entergy Louisiana FTRs Purchased power expense $7.2 (b) Entergy Mississippi FTRs Purchased power expense $6.0 (b) Entergy New Orleans FTRs Purchased power expense ($0.2) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of FTRs for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. Effective first quarter 2016, Entergy retrospectively adopted ASU 2015-07, which simplifies the disclosure for fair value investments by removing the requirement to categorize within the fair value hierarchy investment for which fair value is measured using the net asset value per share as a practical expedient. For all periods presented the common trust funds have not been assigned a level and are presented within the fair value tables only as a reconciling item to the total fair value of investments. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: - quoted prices for similar assets or liabilities in active markets; - quoted prices for identical assets or liabilities in inactive markets; - inputs other than quoted prices that are observable for the asset or liability; or - inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of FTRs and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options. The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available, and uses multiple sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In
Entergy New Orleans [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at June 30, 2016 is approximately 2 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 87% 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 18 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 June 30, 2016 , derivative contracts with four counterparties were in a liability position (approximately $7 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and letters of credit in the amount of $23 million were required to be posted by its counterparties to the Entergy subsidiary as of June 30, 2016. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). As of December 31, 2015, $9 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $68 million was required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate guarantee is typically ignored and Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of short-term natural gas swaps that financially settle against NYMEX futures. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of June 30, 2016 is 32,588,000 MMBtu for Entergy, including 26,370,000 MMBtu for Entergy Louisiana, 5,950,000 MMBtu for Entergy Mississippi, and 268,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests. During the second quarter 2016, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2016 through May 31, 2017. FTRs are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records FTRs at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on FTRs held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on FTRs. The total volume of FTRs outstanding as of June 30, 2016 is 103,995 GWh for Entergy, including 23,627 GWh for Entergy Arkansas, 44,556 GWh for Entergy Louisiana, 16,903 GWh for Entergy Mississippi, 5,064 GWh for Entergy New Orleans, and 13,301 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 June 30, 2016 , letters of credit posted with MISO covered the FTR exposure for Entergy Texas. 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 June 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($9) $41 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $7 ($7) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $7 ($5) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($22) $28 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $8 $— $8 Entergy Wholesale Commodities Natural gas swaps Prepayments and other $16 $— $16 Utility FTRs Prepayments and other $47 ($1) $46 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $31 ($24) $7 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($1) $2 Entergy Wholesale Commodities 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 $1 million posted as of June 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $1 million posted and $23 million held as of June 30, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 2015 Electricity swaps and options $137 Competitive businesses operating revenues $78 (a) Before taxes of $16 million and $27 million for the three months ended June 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 2015 Electricity swaps and options $105 Competitive businesses operating revenues $91 (a) Before taxes of $70 million and $32 million for the six months ended June 30, 2016 and 2015, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended June 30, 2016 and 2015 was ($3) million and $2 million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2016 and 2015 was ($0.3) million and $1 million , respectively. Based on market prices as of June 30, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $53 million . Approximately $51 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 June 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($6) FTRs $— Purchased power expense (b) $38 Electricity swaps and options de-designated as hedged items ($10) Competitive business operating revenues ($6) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $3 FTRs $— Purchased power expense (b) $46 Electricity swaps and options de-designated as hedged items ($3) Competitive business operating revenues ($5) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) FTRs $— Purchased power expense (b) $59 Electricity swaps and options de-designated as hedged items $15 Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) FTRs $— Purchased power expense (b) $79 Electricity swaps and options de-designated as hedged items $1 Competitive business operating revenues ($39) (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 June 30, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $12.8 Entergy Louisiana Natural gas swaps Prepayments and other $2.7 Entergy Mississippi FTRs Prepayments and other $14.0 Entergy Arkansas FTRs Prepayments and other $16.2 Entergy Louisiana FTRs Prepayments and other $5.6 Entergy Mississippi FTRs Prepayments and other $2.0 Entergy New Orleans FTRs Prepayments and other $8.0 Entergy Texas 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 $1.4 million posted by Entergy Texas as of June 30, 2016. No cash collateral was required to be posted as of June 30, 2016 and December 31, 2015, respectively. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy Mississippi FTRs Purchased power expense $5.5 (b) Entergy Arkansas FTRs Purchased power expense $21.6 (b) Entergy Louisiana FTRs Purchased power expense $3.6 (b) Entergy Mississippi FTRs Purchased power expense $1.4 (b) Entergy New Orleans FTRs Purchased power expense $5.4 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $2.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.6 (a) Entergy Mississippi FTRs Purchased power expense $19.6 (b) Entergy Arkansas FTRs Purchased power expense $17.3 (b) Entergy Louisiana FTRs Purchased power expense $3.9 (b) Entergy Mississippi FTRs Purchased power expense $4.5 (b) Entergy New Orleans FTRs Purchased power expense $1.2 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($24.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.0) (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 $13.3 (b) Entergy Arkansas FTRs Purchased power expense $32.1 (b) Entergy Louisiana FTRs Purchased power expense $4.4 (b) Entergy Mississippi FTRs Purchased power expense $1.9 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.5) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.4) (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 $34.7 (b) Entergy Arkansas FTRs Purchased power expense $31.7 (b) Entergy Louisiana FTRs Purchased power expense $7.2 (b) Entergy Mississippi FTRs Purchased power expense $6.0 (b) Entergy New Orleans FTRs Purchased power expense ($0.2) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of FTRs for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. Effective first quarter 2016, Entergy retrospectively adopted ASU 2015-07, which simplifies the disclosure for fair value investments by removing the requirement to categorize within the fair value hierarchy investment for which fair value is measured using the net asset value per share as a practical expedient. For all periods presented the common trust funds have not been assigned a level and are presented within the fair value tables only as a reconciling item to the total fair value of investments. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: - quoted prices for similar assets or liabilities in active markets; - quoted prices for identical assets or liabilities in inactive markets; - inputs other than quoted prices that are observable for the asset or liability; or - inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of FTRs and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options. The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available, and uses multiple sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In
Entergy Texas [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at June 30, 2016 is approximately 2 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 87% 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 18 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 June 30, 2016 , derivative contracts with four counterparties were in a liability position (approximately $7 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and letters of credit in the amount of $23 million were required to be posted by its counterparties to the Entergy subsidiary as of June 30, 2016. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). As of December 31, 2015, $9 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $68 million was required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate guarantee is typically ignored and Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of short-term natural gas swaps that financially settle against NYMEX futures. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of June 30, 2016 is 32,588,000 MMBtu for Entergy, including 26,370,000 MMBtu for Entergy Louisiana, 5,950,000 MMBtu for Entergy Mississippi, and 268,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests. During the second quarter 2016, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2016 through May 31, 2017. FTRs are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records FTRs at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on FTRs held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on FTRs. The total volume of FTRs outstanding as of June 30, 2016 is 103,995 GWh for Entergy, including 23,627 GWh for Entergy Arkansas, 44,556 GWh for Entergy Louisiana, 16,903 GWh for Entergy Mississippi, 5,064 GWh for Entergy New Orleans, and 13,301 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 June 30, 2016 , letters of credit posted with MISO covered the FTR exposure for Entergy Texas. 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 June 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($9) $41 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $7 ($7) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $7 ($5) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($22) $28 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $8 $— $8 Entergy Wholesale Commodities Natural gas swaps Prepayments and other $16 $— $16 Utility FTRs Prepayments and other $47 ($1) $46 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $31 ($24) $7 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($1) $2 Entergy Wholesale Commodities 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 $1 million posted as of June 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $1 million posted and $23 million held as of June 30, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 2015 Electricity swaps and options $137 Competitive businesses operating revenues $78 (a) Before taxes of $16 million and $27 million for the three months ended June 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 2015 Electricity swaps and options $105 Competitive businesses operating revenues $91 (a) Before taxes of $70 million and $32 million for the six months ended June 30, 2016 and 2015, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended June 30, 2016 and 2015 was ($3) million and $2 million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2016 and 2015 was ($0.3) million and $1 million , respectively. Based on market prices as of June 30, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $53 million . Approximately $51 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 June 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($6) FTRs $— Purchased power expense (b) $38 Electricity swaps and options de-designated as hedged items ($10) Competitive business operating revenues ($6) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $3 FTRs $— Purchased power expense (b) $46 Electricity swaps and options de-designated as hedged items ($3) Competitive business operating revenues ($5) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) FTRs $— Purchased power expense (b) $59 Electricity swaps and options de-designated as hedged items $15 Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) FTRs $— Purchased power expense (b) $79 Electricity swaps and options de-designated as hedged items $1 Competitive business operating revenues ($39) (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 June 30, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $12.8 Entergy Louisiana Natural gas swaps Prepayments and other $2.7 Entergy Mississippi FTRs Prepayments and other $14.0 Entergy Arkansas FTRs Prepayments and other $16.2 Entergy Louisiana FTRs Prepayments and other $5.6 Entergy Mississippi FTRs Prepayments and other $2.0 Entergy New Orleans FTRs Prepayments and other $8.0 Entergy Texas 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 $1.4 million posted by Entergy Texas as of June 30, 2016. No cash collateral was required to be posted as of June 30, 2016 and December 31, 2015, respectively. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy Mississippi FTRs Purchased power expense $5.5 (b) Entergy Arkansas FTRs Purchased power expense $21.6 (b) Entergy Louisiana FTRs Purchased power expense $3.6 (b) Entergy Mississippi FTRs Purchased power expense $1.4 (b) Entergy New Orleans FTRs Purchased power expense $5.4 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $2.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.6 (a) Entergy Mississippi FTRs Purchased power expense $19.6 (b) Entergy Arkansas FTRs Purchased power expense $17.3 (b) Entergy Louisiana FTRs Purchased power expense $3.9 (b) Entergy Mississippi FTRs Purchased power expense $4.5 (b) Entergy New Orleans FTRs Purchased power expense $1.2 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($24.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.0) (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 $13.3 (b) Entergy Arkansas FTRs Purchased power expense $32.1 (b) Entergy Louisiana FTRs Purchased power expense $4.4 (b) Entergy Mississippi FTRs Purchased power expense $1.9 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.5) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.4) (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 $34.7 (b) Entergy Arkansas FTRs Purchased power expense $31.7 (b) Entergy Louisiana FTRs Purchased power expense $7.2 (b) Entergy Mississippi FTRs Purchased power expense $6.0 (b) Entergy New Orleans FTRs Purchased power expense ($0.2) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of FTRs for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. Effective first quarter 2016, Entergy retrospectively adopted ASU 2015-07, which simplifies the disclosure for fair value investments by removing the requirement to categorize within the fair value hierarchy investment for which fair value is measured using the net asset value per share as a practical expedient. For all periods presented the common trust funds have not been assigned a level and are presented within the fair value tables only as a reconciling item to the total fair value of investments. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: - quoted prices for similar assets or liabilities in active markets; - quoted prices for identical assets or liabilities in inactive markets; - inputs other than quoted prices that are observable for the asset or liability; or - inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of FTRs and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options. The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available, and uses multiple sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In
System Energy [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at June 30, 2016 is approximately 2 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 87% 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 18 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 June 30, 2016 , derivative contracts with four counterparties were in a liability position (approximately $7 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and letters of credit in the amount of $23 million were required to be posted by its counterparties to the Entergy subsidiary as of June 30, 2016. As of December 31, 2015 , derivative contracts with two counterparties were in a liability position (approximately $2 million total). As of December 31, 2015, $9 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $68 million was required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate guarantee is typically ignored and Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of short-term natural gas swaps that financially settle against NYMEX futures. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of June 30, 2016 is 32,588,000 MMBtu for Entergy, including 26,370,000 MMBtu for Entergy Louisiana, 5,950,000 MMBtu for Entergy Mississippi, and 268,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests. During the second quarter 2016, Entergy participated in the annual FTR auction process for the MISO planning year of June 1, 2016 through May 31, 2017. FTRs are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records FTRs at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on FTRs held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on FTRs. The total volume of FTRs outstanding as of June 30, 2016 is 103,995 GWh for Entergy, including 23,627 GWh for Entergy Arkansas, 44,556 GWh for Entergy Louisiana, 16,903 GWh for Entergy Mississippi, 5,064 GWh for Entergy New Orleans, and 13,301 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 June 30, 2016 , letters of credit posted with MISO covered the FTR exposure for Entergy Texas. 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 June 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($9) $41 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $7 ($7) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $7 ($5) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($22) $28 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $8 $— $8 Entergy Wholesale Commodities Natural gas swaps Prepayments and other $16 $— $16 Utility FTRs Prepayments and other $47 ($1) $46 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $31 ($24) $7 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($1) $2 Entergy Wholesale Commodities 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 $1 million posted as of June 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $1 million posted and $23 million held as of June 30, 2016. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the three months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 2015 Electricity swaps and options $137 Competitive businesses operating revenues $78 (a) Before taxes of $16 million and $27 million for the three months ended June 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 2015 Electricity swaps and options $105 Competitive businesses operating revenues $91 (a) Before taxes of $70 million and $32 million for the six months ended June 30, 2016 and 2015, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended June 30, 2016 and 2015 was ($3) million and $2 million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2016 and 2015 was ($0.3) million and $1 million , respectively. Based on market prices as of June 30, 2016 , net unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $53 million . Approximately $51 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 June 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($6) FTRs $— Purchased power expense (b) $38 Electricity swaps and options de-designated as hedged items ($10) Competitive business operating revenues ($6) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $3 FTRs $— Purchased power expense (b) $46 Electricity swaps and options de-designated as hedged items ($3) Competitive business operating revenues ($5) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) FTRs $— Purchased power expense (b) $59 Electricity swaps and options de-designated as hedged items $15 Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) FTRs $— Purchased power expense (b) $79 Electricity swaps and options de-designated as hedged items $1 Competitive business operating revenues ($39) (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 June 30, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $12.8 Entergy Louisiana Natural gas swaps Prepayments and other $2.7 Entergy Mississippi FTRs Prepayments and other $14.0 Entergy Arkansas FTRs Prepayments and other $16.2 Entergy Louisiana FTRs Prepayments and other $5.6 Entergy Mississippi FTRs Prepayments and other $2.0 Entergy New Orleans FTRs Prepayments and other $8.0 Entergy Texas 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 $1.4 million posted by Entergy Texas as of June 30, 2016. No cash collateral was required to be posted as of June 30, 2016 and December 31, 2015, respectively. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy Mississippi FTRs Purchased power expense $5.5 (b) Entergy Arkansas FTRs Purchased power expense $21.6 (b) Entergy Louisiana FTRs Purchased power expense $3.6 (b) Entergy Mississippi FTRs Purchased power expense $1.4 (b) Entergy New Orleans FTRs Purchased power expense $5.4 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $2.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.6 (a) Entergy Mississippi FTRs Purchased power expense $19.6 (b) Entergy Arkansas FTRs Purchased power expense $17.3 (b) Entergy Louisiana FTRs Purchased power expense $3.9 (b) Entergy Mississippi FTRs Purchased power expense $4.5 (b) Entergy New Orleans FTRs Purchased power expense $1.2 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($24.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.0) (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 $13.3 (b) Entergy Arkansas FTRs Purchased power expense $32.1 (b) Entergy Louisiana FTRs Purchased power expense $4.4 (b) Entergy Mississippi FTRs Purchased power expense $1.9 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.5) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.4) (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 $34.7 (b) Entergy Arkansas FTRs Purchased power expense $31.7 (b) Entergy Louisiana FTRs Purchased power expense $7.2 (b) Entergy Mississippi FTRs Purchased power expense $6.0 (b) Entergy New Orleans FTRs Purchased power expense ($0.2) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of FTRs for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. Effective first quarter 2016, Entergy retrospectively adopted ASU 2015-07, which simplifies the disclosure for fair value investments by removing the requirement to categorize within the fair value hierarchy investment for which fair value is measured using the net asset value per share as a practical expedient. For all periods presented the common trust funds have not been assigned a level and are presented within the fair value tables only as a reconciling item to the total fair value of investments. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: - quoted prices for similar assets or liabilities in active markets; - quoted prices for identical assets or liabilities in inactive markets; - inputs other than quoted prices that are observable for the asset or liability; or - inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of FTRs and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options. The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available, and uses multiple sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In

Decommissioning Trust Funds

Decommissioning Trust Funds	6 Months Ended
	Jun. 30, 2016
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) Entergy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The NRC requires Entergy subsidiaries to maintain trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades (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 June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,283 $1,467 $1 Debt Securities 2,273 108 1 Total $5,556 $1,575 $2 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 $380 million and $342 million as of June 30, 2016 and December 31, 2015 , respectively. The amortized cost of debt securities was $2,189 million as of June 30, 2016 and $2,124 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 3.20% , an average duration of approximately 5.83 years, and an average maturity of approximately 9.22 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $24 $1 $84 $— More than 12 months 1 — 33 1 Total $25 $1 $117 $1 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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $73 $77 1 year - 5 years 839 857 5 years - 10 years 755 704 10 years - 15 years 152 124 15 years - 20 years 63 50 20 years+ 391 343 Total $2,273 $2,155 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $504 million and $456 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $10 million and $19 million , respectively, and gross losses of $2 million and $1 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $1,233 million and $949 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $20 million and $45 million , respectively, and gross losses of $5 million and $3 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 June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $497.6 $246.3 $0.1 Debt Securities 305.2 12.1 0.1 Total $802.8 $258.4 $0.2 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 $299.5 million as of June 30, 2016 and $301.8 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 2.61% , an average duration of approximately 5.19 years, and an average maturity of approximately 5.94 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $4.5 $0.1 $18.2 $— More than 12 months — — 1.6 0.1 Total $4.5 $0.1 $19.8 $0.1 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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $5.4 $1.8 1 year - 5 years 119.9 145.2 5 years - 10 years 163.5 138.5 10 years - 15 years 9.7 2.4 15 years - 20 years 1.1 2.0 20 years+ 5.6 14.0 Total $305.2 $303.9 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $45.2 million and $64.9 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $0.4 million and $0.3 million , respectively, and gross losses of $0.2 million and $0.02 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $103.8 million and $146.8 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $1.2 million and $5.4 million , respectively, and gross losses of $0.3 million and $0.02 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $658.6 $300.4 $— Debt Securities 436.2 24.7 0.3 Total $1,094.8 $325.1 $0.3 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 $413.4 million as of June 30, 2016 and $399.2 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 3.85% , an average duration of approximately 5.47 years, and an average maturity of approximately 11.19 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1.6 $— $3.7 $— More than 12 months 0.8 — 6.8 0.3 Total $2.4 $— $10.5 $0.3 The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $18.9 $27.1 1 year - 5 years 115.0 124.0 5 years - 10 years 117.1 114.3 10 years - 15 years 51.8 39.3 15 years - 20 years 30.9 26.5 20 years+ 102.5 78.7 Total $436.2 $409.9 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $69.7 million and $39.6 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $1.7 million and $0.2 million , respectively, and gross losses of $0.04 million and $0.2 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $123.5 million and $65.2 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $2.6 million and $1.5 million , respectively, and gross losses of $0.1 million and $0.2 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 June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $437.4 $190.0 $0.1 Debt Securities 303.7 8.4 0.1 Total $741.1 $198.4 $0.2 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 $295.2 million as of June 30, 2016 and $270.7 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 1.87% , an average duration of approximately 5.20 years, and an average maturity of approximately 6.35 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1.0 $0.1 $20.2 $— More than 12 months — — 1.1 0.1 Total $1.0 $0.1 $21.3 $0.1 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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $3.1 $2.0 1 year - 5 years 192.2 181.2 5 years - 10 years 75.6 63.0 10 years - 15 years 3.6 4.4 15 years - 20 years 1.5 1.6 20 years+ 27.7 25.6 Total $303.7 $277.8 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $100.9 million and $83.6 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $0.9 million and $0.4 million , respectively, and gross losses of $0.1 million and $0.04 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $289.4 million and $162 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $2.5 million and $0.8 million , respectively, and gross losses of $0.4 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 and six months ended June 30, 2016 and 2015 . The assessment of whether an investment in an equity security has suffered an other-than-temporary impairment continues to be based on a number of factors including, first, whether Entergy has the ability and intent to hold the investment to recover its value, the duration and severity of any losses, and, then, whether it is expected that the investment will recover its value within a reasonable period of time. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. Entergy did not have any material charges relating to other-than-temporary impairment of certain equity securities for the three and six months ended June 30, 2016 and 2015 .
Entergy Arkansas [Member]
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) Entergy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The NRC requires Entergy subsidiaries to maintain trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades (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 June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,283 $1,467 $1 Debt Securities 2,273 108 1 Total $5,556 $1,575 $2 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 $380 million and $342 million as of June 30, 2016 and December 31, 2015 , respectively. The amortized cost of debt securities was $2,189 million as of June 30, 2016 and $2,124 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 3.20% , an average duration of approximately 5.83 years, and an average maturity of approximately 9.22 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $24 $1 $84 $— More than 12 months 1 — 33 1 Total $25 $1 $117 $1 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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $73 $77 1 year - 5 years 839 857 5 years - 10 years 755 704 10 years - 15 years 152 124 15 years - 20 years 63 50 20 years+ 391 343 Total $2,273 $2,155 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $504 million and $456 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $10 million and $19 million , respectively, and gross losses of $2 million and $1 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $1,233 million and $949 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $20 million and $45 million , respectively, and gross losses of $5 million and $3 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 June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $497.6 $246.3 $0.1 Debt Securities 305.2 12.1 0.1 Total $802.8 $258.4 $0.2 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 $299.5 million as of June 30, 2016 and $301.8 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 2.61% , an average duration of approximately 5.19 years, and an average maturity of approximately 5.94 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $4.5 $0.1 $18.2 $— More than 12 months — — 1.6 0.1 Total $4.5 $0.1 $19.8 $0.1 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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $5.4 $1.8 1 year - 5 years 119.9 145.2 5 years - 10 years 163.5 138.5 10 years - 15 years 9.7 2.4 15 years - 20 years 1.1 2.0 20 years+ 5.6 14.0 Total $305.2 $303.9 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $45.2 million and $64.9 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $0.4 million and $0.3 million , respectively, and gross losses of $0.2 million and $0.02 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $103.8 million and $146.8 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $1.2 million and $5.4 million , respectively, and gross losses of $0.3 million and $0.02 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $658.6 $300.4 $— Debt Securities 436.2 24.7 0.3 Total $1,094.8 $325.1 $0.3 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 $413.4 million as of June 30, 2016 and $399.2 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 3.85% , an average duration of approximately 5.47 years, and an average maturity of approximately 11.19 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1.6 $— $3.7 $— More than 12 months 0.8 — 6.8 0.3 Total $2.4 $— $10.5 $0.3 The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $18.9 $27.1 1 year - 5 years 115.0 124.0 5 years - 10 years 117.1 114.3 10 years - 15 years 51.8 39.3 15 years - 20 years 30.9 26.5 20 years+ 102.5 78.7 Total $436.2 $409.9 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $69.7 million and $39.6 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $1.7 million and $0.2 million , respectively, and gross losses of $0.04 million and $0.2 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $123.5 million and $65.2 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $2.6 million and $1.5 million , respectively, and gross losses of $0.1 million and $0.2 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 June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $437.4 $190.0 $0.1 Debt Securities 303.7 8.4 0.1 Total $741.1 $198.4 $0.2 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 $295.2 million as of June 30, 2016 and $270.7 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 1.87% , an average duration of approximately 5.20 years, and an average maturity of approximately 6.35 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1.0 $0.1 $20.2 $— More than 12 months — — 1.1 0.1 Total $1.0 $0.1 $21.3 $0.1 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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $3.1 $2.0 1 year - 5 years 192.2 181.2 5 years - 10 years 75.6 63.0 10 years - 15 years 3.6 4.4 15 years - 20 years 1.5 1.6 20 years+ 27.7 25.6 Total $303.7 $277.8 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $100.9 million and $83.6 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $0.9 million and $0.4 million , respectively, and gross losses of $0.1 million and $0.04 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $289.4 million and $162 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $2.5 million and $0.8 million , respectively, and gross losses of $0.4 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 and six months ended June 30, 2016 and 2015 . The assessment of whether an investment in an equity security has suffered an other-than-temporary impairment continues to be based on a number of factors including, first, whether Entergy has the ability and intent to hold the investment to recover its value, the duration and severity of any losses, and, then, whether it is expected that the investment will recover its value within a reasonable period of time. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. Entergy did not have any material charges relating to other-than-temporary impairment of certain equity securities for the three and six months ended June 30, 2016 and 2015 .
Entergy Louisiana [Member]
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) Entergy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The NRC requires Entergy subsidiaries to maintain trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades (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 June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,283 $1,467 $1 Debt Securities 2,273 108 1 Total $5,556 $1,575 $2 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 $380 million and $342 million as of June 30, 2016 and December 31, 2015 , respectively. The amortized cost of debt securities was $2,189 million as of June 30, 2016 and $2,124 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 3.20% , an average duration of approximately 5.83 years, and an average maturity of approximately 9.22 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $24 $1 $84 $— More than 12 months 1 — 33 1 Total $25 $1 $117 $1 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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $73 $77 1 year - 5 years 839 857 5 years - 10 years 755 704 10 years - 15 years 152 124 15 years - 20 years 63 50 20 years+ 391 343 Total $2,273 $2,155 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $504 million and $456 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $10 million and $19 million , respectively, and gross losses of $2 million and $1 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $1,233 million and $949 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $20 million and $45 million , respectively, and gross losses of $5 million and $3 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 June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $497.6 $246.3 $0.1 Debt Securities 305.2 12.1 0.1 Total $802.8 $258.4 $0.2 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 $299.5 million as of June 30, 2016 and $301.8 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 2.61% , an average duration of approximately 5.19 years, and an average maturity of approximately 5.94 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $4.5 $0.1 $18.2 $— More than 12 months — — 1.6 0.1 Total $4.5 $0.1 $19.8 $0.1 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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $5.4 $1.8 1 year - 5 years 119.9 145.2 5 years - 10 years 163.5 138.5 10 years - 15 years 9.7 2.4 15 years - 20 years 1.1 2.0 20 years+ 5.6 14.0 Total $305.2 $303.9 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $45.2 million and $64.9 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $0.4 million and $0.3 million , respectively, and gross losses of $0.2 million and $0.02 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $103.8 million and $146.8 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $1.2 million and $5.4 million , respectively, and gross losses of $0.3 million and $0.02 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $658.6 $300.4 $— Debt Securities 436.2 24.7 0.3 Total $1,094.8 $325.1 $0.3 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 $413.4 million as of June 30, 2016 and $399.2 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 3.85% , an average duration of approximately 5.47 years, and an average maturity of approximately 11.19 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1.6 $— $3.7 $— More than 12 months 0.8 — 6.8 0.3 Total $2.4 $— $10.5 $0.3 The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $18.9 $27.1 1 year - 5 years 115.0 124.0 5 years - 10 years 117.1 114.3 10 years - 15 years 51.8 39.3 15 years - 20 years 30.9 26.5 20 years+ 102.5 78.7 Total $436.2 $409.9 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $69.7 million and $39.6 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $1.7 million and $0.2 million , respectively, and gross losses of $0.04 million and $0.2 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $123.5 million and $65.2 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $2.6 million and $1.5 million , respectively, and gross losses of $0.1 million and $0.2 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 June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $437.4 $190.0 $0.1 Debt Securities 303.7 8.4 0.1 Total $741.1 $198.4 $0.2 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 $295.2 million as of June 30, 2016 and $270.7 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 1.87% , an average duration of approximately 5.20 years, and an average maturity of approximately 6.35 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1.0 $0.1 $20.2 $— More than 12 months — — 1.1 0.1 Total $1.0 $0.1 $21.3 $0.1 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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $3.1 $2.0 1 year - 5 years 192.2 181.2 5 years - 10 years 75.6 63.0 10 years - 15 years 3.6 4.4 15 years - 20 years 1.5 1.6 20 years+ 27.7 25.6 Total $303.7 $277.8 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $100.9 million and $83.6 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $0.9 million and $0.4 million , respectively, and gross losses of $0.1 million and $0.04 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $289.4 million and $162 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $2.5 million and $0.8 million , respectively, and gross losses of $0.4 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 and six months ended June 30, 2016 and 2015 . The assessment of whether an investment in an equity security has suffered an other-than-temporary impairment continues to be based on a number of factors including, first, whether Entergy has the ability and intent to hold the investment to recover its value, the duration and severity of any losses, and, then, whether it is expected that the investment will recover its value within a reasonable period of time. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. Entergy did not have any material charges relating to other-than-temporary impairment of certain equity securities for the three and six months ended June 30, 2016 and 2015 .
System Energy [Member]
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) Entergy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The NRC requires Entergy subsidiaries to maintain trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades (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 June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,283 $1,467 $1 Debt Securities 2,273 108 1 Total $5,556 $1,575 $2 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 $380 million and $342 million as of June 30, 2016 and December 31, 2015 , respectively. The amortized cost of debt securities was $2,189 million as of June 30, 2016 and $2,124 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 3.20% , an average duration of approximately 5.83 years, and an average maturity of approximately 9.22 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $24 $1 $84 $— More than 12 months 1 — 33 1 Total $25 $1 $117 $1 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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $73 $77 1 year - 5 years 839 857 5 years - 10 years 755 704 10 years - 15 years 152 124 15 years - 20 years 63 50 20 years+ 391 343 Total $2,273 $2,155 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $504 million and $456 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $10 million and $19 million , respectively, and gross losses of $2 million and $1 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $1,233 million and $949 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $20 million and $45 million , respectively, and gross losses of $5 million and $3 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 June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $497.6 $246.3 $0.1 Debt Securities 305.2 12.1 0.1 Total $802.8 $258.4 $0.2 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 $299.5 million as of June 30, 2016 and $301.8 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 2.61% , an average duration of approximately 5.19 years, and an average maturity of approximately 5.94 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $4.5 $0.1 $18.2 $— More than 12 months — — 1.6 0.1 Total $4.5 $0.1 $19.8 $0.1 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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $5.4 $1.8 1 year - 5 years 119.9 145.2 5 years - 10 years 163.5 138.5 10 years - 15 years 9.7 2.4 15 years - 20 years 1.1 2.0 20 years+ 5.6 14.0 Total $305.2 $303.9 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $45.2 million and $64.9 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $0.4 million and $0.3 million , respectively, and gross losses of $0.2 million and $0.02 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $103.8 million and $146.8 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $1.2 million and $5.4 million , respectively, and gross losses of $0.3 million and $0.02 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $658.6 $300.4 $— Debt Securities 436.2 24.7 0.3 Total $1,094.8 $325.1 $0.3 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 $413.4 million as of June 30, 2016 and $399.2 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 3.85% , an average duration of approximately 5.47 years, and an average maturity of approximately 11.19 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1.6 $— $3.7 $— More than 12 months 0.8 — 6.8 0.3 Total $2.4 $— $10.5 $0.3 The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $18.9 $27.1 1 year - 5 years 115.0 124.0 5 years - 10 years 117.1 114.3 10 years - 15 years 51.8 39.3 15 years - 20 years 30.9 26.5 20 years+ 102.5 78.7 Total $436.2 $409.9 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $69.7 million and $39.6 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $1.7 million and $0.2 million , respectively, and gross losses of $0.04 million and $0.2 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $123.5 million and $65.2 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $2.6 million and $1.5 million , respectively, and gross losses of $0.1 million and $0.2 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 June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $437.4 $190.0 $0.1 Debt Securities 303.7 8.4 0.1 Total $741.1 $198.4 $0.2 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 $295.2 million as of June 30, 2016 and $270.7 million as of December 31, 2015 . As of June 30, 2016 , the debt securities have an average coupon rate of approximately 1.87% , an average duration of approximately 5.20 years, and an average maturity of approximately 6.35 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1.0 $0.1 $20.2 $— More than 12 months — — 1.1 0.1 Total $1.0 $0.1 $21.3 $0.1 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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $3.1 $2.0 1 year - 5 years 192.2 181.2 5 years - 10 years 75.6 63.0 10 years - 15 years 3.6 4.4 15 years - 20 years 1.5 1.6 20 years+ 27.7 25.6 Total $303.7 $277.8 During the three months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $100.9 million and $83.6 million , respectively. During the three months ended June 30, 2016 and 2015 , gross gains of $0.9 million and $0.4 million , respectively, and gross losses of $0.1 million and $0.04 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2016 and 2015 , proceeds from the dispositions of securities amounted to $289.4 million and $162 million , respectively. During the six months ended June 30, 2016 and 2015 , gross gains of $2.5 million and $0.8 million , respectively, and gross losses of $0.4 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 and six months ended June 30, 2016 and 2015 . The assessment of whether an investment in an equity security has suffered an other-than-temporary impairment continues to be based on a number of factors including, first, whether Entergy has the ability and intent to hold the investment to recover its value, the duration and severity of any losses, and, then, whether it is expected that the investment will recover its value within a reasonable period of time. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. Entergy did not have any material charges relating to other-than-temporary impairment of certain equity securities for the three and six months ended June 30, 2016 and 2015 .

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2016
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Litigation ,” “ Income Tax Audits ,” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax proceedings, income tax audits, and other income tax matters involving Entergy. The following are updates to that discussion. 2010-2011 IRS Audit The IRS has completed its examination of the 2010 and 2011 tax years and issued its 2010-2011 Revenue Agent Report (RAR) in June 2016. Entergy has agreed to all proposed adjustments contained in the RAR. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits as follows: • Entergy and the IRS agreed that $148.6 million of the proceeds received by Entergy Louisiana in 2010 from the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, for the financing of Hurricane Gustav and Hurricane Ike storm costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Louisiana Act 55) were not taxable. Because the treatment of the financing is settled, Entergy recognized previously unrecognized tax benefits totaling $63.5 million , of which Entergy Louisiana recorded $61.6 million . Entergy Louisiana also accrued a regulatory liability of $16.1 million ( $9.9 million net-of-tax) in accordance with the terms of Entergy Louisiana’s previous settlement agreement approved by the LPSC regarding Entergy Louisiana’s obligation to pay to customers savings associated with the Act 55 financing. • Entergy and the IRS agreed upon the tax treatment of Entergy Louisiana’s regulatory liability related to the Vidalia purchased power agreement. As a result, Entergy Louisiana recognized a previously unrecognized tax benefit of $74.5 million . The settlement of the above-described items, along with other minor recorded adjustments, decreased Entergy Louisiana’s balance of unrecognized tax benefits from $796.9 million as of December 31, 2015 to $564.7 million as of June 30, 2016, net of carryovers for losses and credits. The unrecognized tax benefits were settled primarily through utilization of net operating loss carryovers. Other Tax Matters Entergy made a tax election to treat its subsidiary that owns one of the Entergy Wholesale Commodities nuclear power plants as a corporation for federal income tax purposes. This resulted in a constructive contribution of all the assets and liabilities associated with the plant to a new subsidiary corporation for federal income tax purposes. The constructive contribution required Entergy to recognize the plant’s nuclear decommissioning liability for income tax purposes resulting in permanent differences under the income tax accounting standards. The accrual of the nuclear decommissioning liability required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiary. The permanent difference reduced income tax expense, net of unrecognized tax benefits, by $238 million .
Entergy Arkansas [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Litigation ,” “ Income Tax Audits ,” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax proceedings, income tax audits, and other income tax matters involving Entergy. The following are updates to that discussion. 2010-2011 IRS Audit The IRS has completed its examination of the 2010 and 2011 tax years and issued its 2010-2011 Revenue Agent Report (RAR) in June 2016. Entergy has agreed to all proposed adjustments contained in the RAR. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits as follows: • Entergy and the IRS agreed that $148.6 million of the proceeds received by Entergy Louisiana in 2010 from the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, for the financing of Hurricane Gustav and Hurricane Ike storm costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Louisiana Act 55) were not taxable. Because the treatment of the financing is settled, Entergy recognized previously unrecognized tax benefits totaling $63.5 million , of which Entergy Louisiana recorded $61.6 million . Entergy Louisiana also accrued a regulatory liability of $16.1 million ( $9.9 million net-of-tax) in accordance with the terms of Entergy Louisiana’s previous settlement agreement approved by the LPSC regarding Entergy Louisiana’s obligation to pay to customers savings associated with the Act 55 financing. • Entergy and the IRS agreed upon the tax treatment of Entergy Louisiana’s regulatory liability related to the Vidalia purchased power agreement. As a result, Entergy Louisiana recognized a previously unrecognized tax benefit of $74.5 million . The settlement of the above-described items, along with other minor recorded adjustments, decreased Entergy Louisiana’s balance of unrecognized tax benefits from $796.9 million as of December 31, 2015 to $564.7 million as of June 30, 2016, net of carryovers for losses and credits. The unrecognized tax benefits were settled primarily through utilization of net operating loss carryovers. Other Tax Matters Entergy made a tax election to treat its subsidiary that owns one of the Entergy Wholesale Commodities nuclear power plants as a corporation for federal income tax purposes. This resulted in a constructive contribution of all the assets and liabilities associated with the plant to a new subsidiary corporation for federal income tax purposes. The constructive contribution required Entergy to recognize the plant’s nuclear decommissioning liability for income tax purposes resulting in permanent differences under the income tax accounting standards. The accrual of the nuclear decommissioning liability required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiary. The permanent difference reduced income tax expense, net of unrecognized tax benefits, by $238 million .
Entergy Louisiana [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Litigation ,” “ Income Tax Audits ,” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax proceedings, income tax audits, and other income tax matters involving Entergy. The following are updates to that discussion. 2010-2011 IRS Audit The IRS has completed its examination of the 2010 and 2011 tax years and issued its 2010-2011 Revenue Agent Report (RAR) in June 2016. Entergy has agreed to all proposed adjustments contained in the RAR. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits as follows: • Entergy and the IRS agreed that $148.6 million of the proceeds received by Entergy Louisiana in 2010 from the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, for the financing of Hurricane Gustav and Hurricane Ike storm costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Louisiana Act 55) were not taxable. Because the treatment of the financing is settled, Entergy recognized previously unrecognized tax benefits totaling $63.5 million , of which Entergy Louisiana recorded $61.6 million . Entergy Louisiana also accrued a regulatory liability of $16.1 million ( $9.9 million net-of-tax) in accordance with the terms of Entergy Louisiana’s previous settlement agreement approved by the LPSC regarding Entergy Louisiana’s obligation to pay to customers savings associated with the Act 55 financing. • Entergy and the IRS agreed upon the tax treatment of Entergy Louisiana’s regulatory liability related to the Vidalia purchased power agreement. As a result, Entergy Louisiana recognized a previously unrecognized tax benefit of $74.5 million . The settlement of the above-described items, along with other minor recorded adjustments, decreased Entergy Louisiana’s balance of unrecognized tax benefits from $796.9 million as of December 31, 2015 to $564.7 million as of June 30, 2016, net of carryovers for losses and credits. The unrecognized tax benefits were settled primarily through utilization of net operating loss carryovers. Other Tax Matters Entergy made a tax election to treat its subsidiary that owns one of the Entergy Wholesale Commodities nuclear power plants as a corporation for federal income tax purposes. This resulted in a constructive contribution of all the assets and liabilities associated with the plant to a new subsidiary corporation for federal income tax purposes. The constructive contribution required Entergy to recognize the plant’s nuclear decommissioning liability for income tax purposes resulting in permanent differences under the income tax accounting standards. The accrual of the nuclear decommissioning liability required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiary. The permanent difference reduced income tax expense, net of unrecognized tax benefits, by $238 million .
Entergy Mississippi [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Litigation ,” “ Income Tax Audits ,” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax proceedings, income tax audits, and other income tax matters involving Entergy. The following are updates to that discussion. 2010-2011 IRS Audit The IRS has completed its examination of the 2010 and 2011 tax years and issued its 2010-2011 Revenue Agent Report (RAR) in June 2016. Entergy has agreed to all proposed adjustments contained in the RAR. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits as follows: • Entergy and the IRS agreed that $148.6 million of the proceeds received by Entergy Louisiana in 2010 from the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, for the financing of Hurricane Gustav and Hurricane Ike storm costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Louisiana Act 55) were not taxable. Because the treatment of the financing is settled, Entergy recognized previously unrecognized tax benefits totaling $63.5 million , of which Entergy Louisiana recorded $61.6 million . Entergy Louisiana also accrued a regulatory liability of $16.1 million ( $9.9 million net-of-tax) in accordance with the terms of Entergy Louisiana’s previous settlement agreement approved by the LPSC regarding Entergy Louisiana’s obligation to pay to customers savings associated with the Act 55 financing. • Entergy and the IRS agreed upon the tax treatment of Entergy Louisiana’s regulatory liability related to the Vidalia purchased power agreement. As a result, Entergy Louisiana recognized a previously unrecognized tax benefit of $74.5 million . The settlement of the above-described items, along with other minor recorded adjustments, decreased Entergy Louisiana’s balance of unrecognized tax benefits from $796.9 million as of December 31, 2015 to $564.7 million as of June 30, 2016, net of carryovers for losses and credits. The unrecognized tax benefits were settled primarily through utilization of net operating loss carryovers. Other Tax Matters Entergy made a tax election to treat its subsidiary that owns one of the Entergy Wholesale Commodities nuclear power plants as a corporation for federal income tax purposes. This resulted in a constructive contribution of all the assets and liabilities associated with the plant to a new subsidiary corporation for federal income tax purposes. The constructive contribution required Entergy to recognize the plant’s nuclear decommissioning liability for income tax purposes resulting in permanent differences under the income tax accounting standards. The accrual of the nuclear decommissioning liability required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiary. The permanent difference reduced income tax expense, net of unrecognized tax benefits, by $238 million .
Entergy New Orleans [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Litigation ,” “ Income Tax Audits ,” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax proceedings, income tax audits, and other income tax matters involving Entergy. The following are updates to that discussion. 2010-2011 IRS Audit The IRS has completed its examination of the 2010 and 2011 tax years and issued its 2010-2011 Revenue Agent Report (RAR) in June 2016. Entergy has agreed to all proposed adjustments contained in the RAR. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits as follows: • Entergy and the IRS agreed that $148.6 million of the proceeds received by Entergy Louisiana in 2010 from the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, for the financing of Hurricane Gustav and Hurricane Ike storm costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Louisiana Act 55) were not taxable. Because the treatment of the financing is settled, Entergy recognized previously unrecognized tax benefits totaling $63.5 million , of which Entergy Louisiana recorded $61.6 million . Entergy Louisiana also accrued a regulatory liability of $16.1 million ( $9.9 million net-of-tax) in accordance with the terms of Entergy Louisiana’s previous settlement agreement approved by the LPSC regarding Entergy Louisiana’s obligation to pay to customers savings associated with the Act 55 financing. • Entergy and the IRS agreed upon the tax treatment of Entergy Louisiana’s regulatory liability related to the Vidalia purchased power agreement. As a result, Entergy Louisiana recognized a previously unrecognized tax benefit of $74.5 million . The settlement of the above-described items, along with other minor recorded adjustments, decreased Entergy Louisiana’s balance of unrecognized tax benefits from $796.9 million as of December 31, 2015 to $564.7 million as of June 30, 2016, net of carryovers for losses and credits. The unrecognized tax benefits were settled primarily through utilization of net operating loss carryovers. Other Tax Matters Entergy made a tax election to treat its subsidiary that owns one of the Entergy Wholesale Commodities nuclear power plants as a corporation for federal income tax purposes. This resulted in a constructive contribution of all the assets and liabilities associated with the plant to a new subsidiary corporation for federal income tax purposes. The constructive contribution required Entergy to recognize the plant’s nuclear decommissioning liability for income tax purposes resulting in permanent differences under the income tax accounting standards. The accrual of the nuclear decommissioning liability required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiary. The permanent difference reduced income tax expense, net of unrecognized tax benefits, by $238 million .
Entergy Texas [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Litigation ,” “ Income Tax Audits ,” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax proceedings, income tax audits, and other income tax matters involving Entergy. The following are updates to that discussion. 2010-2011 IRS Audit The IRS has completed its examination of the 2010 and 2011 tax years and issued its 2010-2011 Revenue Agent Report (RAR) in June 2016. Entergy has agreed to all proposed adjustments contained in the RAR. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits as follows: • Entergy and the IRS agreed that $148.6 million of the proceeds received by Entergy Louisiana in 2010 from the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, for the financing of Hurricane Gustav and Hurricane Ike storm costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Louisiana Act 55) were not taxable. Because the treatment of the financing is settled, Entergy recognized previously unrecognized tax benefits totaling $63.5 million , of which Entergy Louisiana recorded $61.6 million . Entergy Louisiana also accrued a regulatory liability of $16.1 million ( $9.9 million net-of-tax) in accordance with the terms of Entergy Louisiana’s previous settlement agreement approved by the LPSC regarding Entergy Louisiana’s obligation to pay to customers savings associated with the Act 55 financing. • Entergy and the IRS agreed upon the tax treatment of Entergy Louisiana’s regulatory liability related to the Vidalia purchased power agreement. As a result, Entergy Louisiana recognized a previously unrecognized tax benefit of $74.5 million . The settlement of the above-described items, along with other minor recorded adjustments, decreased Entergy Louisiana’s balance of unrecognized tax benefits from $796.9 million as of December 31, 2015 to $564.7 million as of June 30, 2016, net of carryovers for losses and credits. The unrecognized tax benefits were settled primarily through utilization of net operating loss carryovers. Other Tax Matters Entergy made a tax election to treat its subsidiary that owns one of the Entergy Wholesale Commodities nuclear power plants as a corporation for federal income tax purposes. This resulted in a constructive contribution of all the assets and liabilities associated with the plant to a new subsidiary corporation for federal income tax purposes. The constructive contribution required Entergy to recognize the plant’s nuclear decommissioning liability for income tax purposes resulting in permanent differences under the income tax accounting standards. The accrual of the nuclear decommissioning liability required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiary. The permanent difference reduced income tax expense, net of unrecognized tax benefits, by $238 million .
System Energy [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Litigation ,” “ Income Tax Audits ,” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax proceedings, income tax audits, and other income tax matters involving Entergy. The following are updates to that discussion. 2010-2011 IRS Audit The IRS has completed its examination of the 2010 and 2011 tax years and issued its 2010-2011 Revenue Agent Report (RAR) in June 2016. Entergy has agreed to all proposed adjustments contained in the RAR. As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits as follows: • Entergy and the IRS agreed that $148.6 million of the proceeds received by Entergy Louisiana in 2010 from the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, for the financing of Hurricane Gustav and Hurricane Ike storm costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Louisiana Act 55) were not taxable. Because the treatment of the financing is settled, Entergy recognized previously unrecognized tax benefits totaling $63.5 million , of which Entergy Louisiana recorded $61.6 million . Entergy Louisiana also accrued a regulatory liability of $16.1 million ( $9.9 million net-of-tax) in accordance with the terms of Entergy Louisiana’s previous settlement agreement approved by the LPSC regarding Entergy Louisiana’s obligation to pay to customers savings associated with the Act 55 financing. • Entergy and the IRS agreed upon the tax treatment of Entergy Louisiana’s regulatory liability related to the Vidalia purchased power agreement. As a result, Entergy Louisiana recognized a previously unrecognized tax benefit of $74.5 million . The settlement of the above-described items, along with other minor recorded adjustments, decreased Entergy Louisiana’s balance of unrecognized tax benefits from $796.9 million as of December 31, 2015 to $564.7 million as of June 30, 2016, net of carryovers for losses and credits. The unrecognized tax benefits were settled primarily through utilization of net operating loss carryovers. Other Tax Matters Entergy made a tax election to treat its subsidiary that owns one of the Entergy Wholesale Commodities nuclear power plants as a corporation for federal income tax purposes. This resulted in a constructive contribution of all the assets and liabilities associated with the plant to a new subsidiary corporation for federal income tax purposes. The constructive contribution required Entergy to recognize the plant’s nuclear decommissioning liability for income tax purposes resulting in permanent differences under the income tax accounting standards. The accrual of the nuclear decommissioning liability required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiary. The permanent difference reduced income tax expense, net of unrecognized tax benefits, by $238 million .

Property, Plant, And Equipment

Property, Plant, And Equipment	6 Months Ended
	Jun. 30, 2016
Property, Plant And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at June 30, 2016 are $138 million for Entergy, $20.4 million for Entergy Arkansas, $43.3 million for Entergy Louisiana, $2.3 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, $11.5 million for Entergy Texas, and $11.8 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 June 30, 2016 are $138 million for Entergy, $20.4 million for Entergy Arkansas, $43.3 million for Entergy Louisiana, $2.3 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, $11.5 million for Entergy Texas, and $11.8 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 June 30, 2016 are $138 million for Entergy, $20.4 million for Entergy Arkansas, $43.3 million for Entergy Louisiana, $2.3 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, $11.5 million for Entergy Texas, and $11.8 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 June 30, 2016 are $138 million for Entergy, $20.4 million for Entergy Arkansas, $43.3 million for Entergy Louisiana, $2.3 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, $11.5 million for Entergy Texas, and $11.8 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 June 30, 2016 are $138 million for Entergy, $20.4 million for Entergy Arkansas, $43.3 million for Entergy Louisiana, $2.3 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, $11.5 million for Entergy Texas, and $11.8 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 June 30, 2016 are $138 million for Entergy, $20.4 million for Entergy Arkansas, $43.3 million for Entergy Louisiana, $2.3 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, $11.5 million for Entergy Texas, and $11.8 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 June 30, 2016 are $138 million for Entergy, $20.4 million for Entergy Arkansas, $43.3 million for Entergy Louisiana, $2.3 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, $11.5 million for Entergy Texas, and $11.8 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	6 Months Ended
	Jun. 30, 2016
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 18 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. Entergy Louisiana was considered to hold a variable interest in the lessor from which it leased an undivided interest representing approximately 9.3% of the Waterford 3 nuclear plant. After Entergy Louisiana acquired a beneficial interest in the leased assets in March 2016, however, the lessor was no longer considered a variable interest entity. Entergy Louisiana made payments on its lease, including interest, of $9.2 million and $21 million in the six months ended June 30, 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 six months ended June 30, 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 six months ended June 30, 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 six months ended June 30, 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 six months ended June 30, 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 six months ended June 30, 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 six months ended June 30, 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 six months ended June 30, 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 six months ended June 30, 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 six months ended June 30, 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 six months ended June 30, 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 six months ended June 30, 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 six months ended June 30, 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 six months ended June 30, 2016 and 2015 , respectively.

Acquisitions Acquisitions

Acquisitions Acquisitions	6 Months Ended
	Jun. 30, 2016
Business Acquisition [Line Items]
Acquisitions [Text Block]	ACQUISITIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans) In March 2016, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans purchased the Union Power Station, a 1,980 MW (summer rating) power generation facility located near El Dorado, Arkansas, from Union Power Partners, L.P. The Union Power Station consists of four natural gas-fired, combined-cycle gas turbine power blocks, each rated at 495 MW (summer rating). Entergy Louisiana purchased two of the power blocks and a 50% undivided ownership interest in certain assets related to the facility, and Entergy Arkansas and Entergy New Orleans each purchased one power block and a 25% undivided ownership interest in such related assets. The aggregate purchase price for the Union Power Station was approximately $949 million (approximately $237 million for each power block and associated assets).
Entergy Arkansas [Member]
Business Acquisition [Line Items]
Acquisitions [Text Block]	ACQUISITIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans) In March 2016, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans purchased the Union Power Station, a 1,980 MW (summer rating) power generation facility located near El Dorado, Arkansas, from Union Power Partners, L.P. The Union Power Station consists of four natural gas-fired, combined-cycle gas turbine power blocks, each rated at 495 MW (summer rating). Entergy Louisiana purchased two of the power blocks and a 50% undivided ownership interest in certain assets related to the facility, and Entergy Arkansas and Entergy New Orleans each purchased one power block and a 25% undivided ownership interest in such related assets. The aggregate purchase price for the Union Power Station was approximately $949 million (approximately $237 million for each power block and associated assets).
Entergy Louisiana [Member]
Business Acquisition [Line Items]
Acquisitions [Text Block]	ACQUISITIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans) In March 2016, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans purchased the Union Power Station, a 1,980 MW (summer rating) power generation facility located near El Dorado, Arkansas, from Union Power Partners, L.P. The Union Power Station consists of four natural gas-fired, combined-cycle gas turbine power blocks, each rated at 495 MW (summer rating). Entergy Louisiana purchased two of the power blocks and a 50% undivided ownership interest in certain assets related to the facility, and Entergy Arkansas and Entergy New Orleans each purchased one power block and a 25% undivided ownership interest in such related assets. The aggregate purchase price for the Union Power Station was approximately $949 million (approximately $237 million for each power block and associated assets).
Entergy New Orleans [Member]
Business Acquisition [Line Items]
Acquisitions [Text Block]	ACQUISITIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans) In March 2016, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans purchased the Union Power Station, a 1,980 MW (summer rating) power generation facility located near El Dorado, Arkansas, from Union Power Partners, L.P. The Union Power Station consists of four natural gas-fired, combined-cycle gas turbine power blocks, each rated at 495 MW (summer rating). Entergy Louisiana purchased two of the power blocks and a 50% undivided ownership interest in certain assets related to the facility, and Entergy Arkansas and Entergy New Orleans each purchased one power block and a 25% undivided ownership interest in such related assets. The aggregate purchase price for the Union Power Station was approximately $949 million (approximately $237 million for each power block and associated assets).

Equity (Tables)

Equity (Tables)	6 Months Ended
	Jun. 30, 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 June 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $567.3 178.8 $3.17 $148.8 179.5 $0.83 Average dilutive effect of: Stock options 0.2 — 0.2 — Other equity plans 0.5 (0.01 ) 0.4 — Diluted earnings per share $567.3 179.5 $3.16 $148.8 180.1 $0.83 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 4.1 million for the three months ended June 30, 2016 and approximately 5.1 million for the three months ended June 30, 2015 . For the Six Months Ended June 30, 2016 2015 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $797.3 178.7 $4.46 $446.9 179.6 $2.49 Average dilutive effect of: Stock options 0.1 — 0.4 (0.01 ) Other equity plans 0.4 (0.01 ) 0.3 — Diluted earnings per share $797.3 179.2 $4.45 $446.9 180.3 $2.48
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 June 30, 2016 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, April 1, 2016 $96,464 ($459,042 ) $390,626 $1,744 $29,792 Other comprehensive income (loss) before reclassifications (34,138 ) — 24,016 (904 ) (11,026 ) Amounts reclassified from accumulated other comprehensive income (loss) (29,903 ) 5,043 (3,061 ) — (27,921 ) Net other comprehensive income (loss) for the period (64,041 ) 5,043 20,955 (904 ) (38,947 ) Ending balance, June 30, 2016 $32,423 ($453,999 ) $411,581 $840 ($9,155 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 2015 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, April 1, 2015 $68,788 ($561,341 ) $430,698 $2,118 ($59,737 ) Other comprehensive income (loss) before reclassifications 88,796 — (25,108 ) 667 64,355 Amounts reclassified from accumulated other comprehensive income (loss) (50,100 ) 7,438 (8,772 ) — (51,434 ) Net other comprehensive income (loss) for the period 38,696 7,438 (33,880 ) 667 12,921 Ending balance, June 30, 2015 $107,484 ($553,903 ) $396,818 $2,785 ($46,816 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2016 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, January 1, 2016 $105,970 ($466,604 ) $367,557 $2,028 $8,951 Other comprehensive income (loss) before reclassifications 56,169 — 49,048 (1,188 ) 104,029 Amounts reclassified from accumulated other comprehensive income (loss) (129,716 ) 12,605 (5,024 ) — (122,135 ) Net other comprehensive income (loss) for the period (73,547 ) 12,605 44,024 (1,188 ) (18,106 ) Ending balance, June 30, 2016 $32,423 ($453,999 ) $411,581 $840 ($9,155 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2015 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, January 1, 2015 $98,118 ($569,789 ) $426,695 $2,669 ($42,307 ) Other comprehensive income (loss) before reclassifications 67,900 13 (12,450 ) 116 55,579 Amounts reclassified from accumulated other comprehensive income (loss) (58,534 ) 15,873 (17,427 ) — (60,088 ) Net other comprehensive income (loss) for the period 9,366 15,886 (29,877 ) 116 (4,509 ) Ending balance, June 30, 2015 $107,484 ($553,903 ) $396,818 $2,785 ($46,816 )
Reclassification out of Accumulated Other Comprehensive Income	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended June 30, 2016 are as follows: Amounts reclassified from AOCI Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $45,975 Competitive business operating revenues Interest rate swaps 30 Miscellaneous - net Total realized gain (loss) on cash flow hedges 46,005 (16,102 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $29,903 Pension and other postretirement liabilities Amortization of prior-service credit $7,355 (a) Amortization of loss (15,177 ) (a) Total amortization (7,822 ) 2,779 Income taxes Total amortization (net of tax) ($5,043 ) Net unrealized investment gain (loss) Realized gain (loss) $6,000 Interest and investment income (2,939 ) Income taxes Total realized investment gain (loss) (net of tax) $3,061 Total reclassifications for the period (net of tax) $27,921 (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 June 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $77,587 Competitive business operating revenues Interest rate swaps (510 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 77,077 (26,977 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $50,100 Pension and other postretirement liabilities Amortization of prior-service credit $5,985 (a) Amortization of loss (17,588 ) (a) Total amortization (11,603 ) 4,165 Income taxes Total amortization (net of tax) ($7,438 ) Net unrealized investment gain (loss) Realized gain (loss) $17,201 Interest and investment income (8,429 ) Income taxes Total realized investment gain (loss) (net of tax) $8,772 Total reclassifications for the period (net of tax) $51,434 (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 six months ended June 30, 2016 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $199,933 Competitive business operating revenues Interest rate swaps (370 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 199,563 (69,847 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $129,716 Pension and other postretirement liabilities Amortization of prior-service credit $14,710 (a) Amortization of loss (30,352 ) (a) Total amortization (15,642 ) 3,037 Income taxes Total amortization (net of tax) ($12,605 ) Net unrealized investment gain (loss) Realized gain (loss) $9,850 Interest and investment income (4,826 ) Income taxes Total realized investment gain (loss) (net of tax) $5,024 Total reclassifications for the period (net of tax) $122,135 (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 six months ended June 30, 2015 are as follows: Amounts Income Statement Location (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $91,109 Competitive business operating revenues Interest rate swaps (1,056 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 90,053 (31,519 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $58,534 Pension and other postretirement liabilities Amortization of prior-service credit $11,971 (a) Amortization of loss (35,176 ) (a) Total amortization (23,205 ) 7,332 Income taxes Total amortization (net of tax) ($15,873 ) Net unrealized investment gain (loss) Realized gain (loss) $34,171 Interest and investment income (16,744 ) Income taxes Total realized investment gain (loss) (net of tax) $17,427 Total reclassifications for the period (net of tax) $60,088 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.
Entergy Louisiana [Member]
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended June 30, 2016: Pension and Other (In Thousands) Beginning balance April 1, 2016 ($56,675 ) Amounts reclassified from accumulated other (230 ) Net other comprehensive income (loss) for the period (230 ) Ending balance, June 30, 2016 ($56,905 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended June 30, 2015: Pension and Other (In Thousands) Beginning balance April 1, 2015 ($78,843 ) Amounts reclassified from accumulated other 412 Net other comprehensive income (loss) for the period 412 Ending balance, June 30, 2015 ($78,431 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2016: Pension and Other (In Thousands) Beginning balance, January 1, 2016 ($56,412 ) Amounts reclassified from accumulated other (493 ) Net other comprehensive income (loss) for the period (493 ) Ending balance, June 30, 2016 ($56,905 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2015: Pension and Other (In Thousands) Beginning balance, January 1, 2015 ($79,223 ) Amounts reclassified from accumulated other 792 Net other comprehensive income (loss) for the period 792 Ending balance, June 30, 2015 ($78,431 )
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 June 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,947 (a) Amortization of loss (1,573 ) (a) Total amortization 374 (144 ) Income taxes Total amortization (net of tax) 230 Total reclassifications for the period (net of tax) $230 (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 June 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,866 (a) Amortization of loss (2,535 ) (a) Total amortization (669 ) 257 Income taxes Total amortization (net of tax) (412 ) Total reclassifications for the period (net of tax) ($412 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the six months ended June 30, 2016 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $3,894 (a) Amortization of loss (3,142 ) (a) Total amortization 752 (259 ) Income taxes Total amortization (net of tax) 493 Total reclassifications for the period (net of tax) $493 (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 six months ended June 30, 2015 are as follows: Amounts reclassified Income Statement Location (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $3,733 (a) Amortization of loss (5,070 ) (a) Total amortization (1,337 ) 545 Income taxes Total amortization (net of tax) (792 ) Total reclassifications for the period (net of tax) ($792 ) (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)	6 Months Ended
	Jun. 30, 2016
Summary Of The Borrowings Outstanding And Capacity Available Under The Facility	Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2016 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $240 $6 $3,254
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2016 Letters of Credit Outstanding as of June 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.71% $— $— Entergy Arkansas August 2020 $150 million (c) 1.71% $— $— Entergy Louisiana August 2020 $350 million (d) 1.71% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 1.96% $— $— Entergy Mississippi May 2017 $35 million (e) 1.96% $— $— Entergy Mississippi May 2017 $20 million (e) 1.96% $— $— Entergy Mississippi May 2017 $10 million (e) 1.96% $— $— Entergy New Orleans November 2018 $25 million (f) 2.21% $— $— Entergy Texas August 2020 $150 million (g) 1.96% $— $1.3 million (a) The interest rate is the rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $59.1 million Entergy Mississippi $40 million 0.70% $26.7 million Entergy New Orleans $15 million 0.75% $13.3 million Entergy Texas $50 million 0.70% $14.4 million (a) The amount for Entergy Texas includes $1.4 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 June 30, 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	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 June 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.075% $12.6 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 1.95% $59.5 (b) System Energy VIE May 2019 $120 2.075% $99.6 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) Commercial paper, classified as a current liability.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 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 June 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,783,804 $14,556,026 Entergy Arkansas $2,830,658 $2,835,020 Entergy Louisiana $5,410,218 $5,859,090 Entergy Mississippi $1,091,938 $1,153,791 Entergy New Orleans $459,095 $466,368 Entergy Texas $1,539,889 $1,704,985 System Energy $550,926 $543,935 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 million at Entergy Arkansas, and 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 June 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2016 Letters of Credit Outstanding as of June 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.71% $— $— Entergy Arkansas August 2020 $150 million (c) 1.71% $— $— Entergy Louisiana August 2020 $350 million (d) 1.71% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 1.96% $— $— Entergy Mississippi May 2017 $35 million (e) 1.96% $— $— Entergy Mississippi May 2017 $20 million (e) 1.96% $— $— Entergy Mississippi May 2017 $10 million (e) 1.96% $— $— Entergy New Orleans November 2018 $25 million (f) 2.21% $— $— Entergy Texas August 2020 $150 million (g) 1.96% $— $1.3 million (a) The interest rate is the rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $59.1 million Entergy Mississippi $40 million 0.70% $26.7 million Entergy New Orleans $15 million 0.75% $13.3 million Entergy Texas $50 million 0.70% $14.4 million (a) The amount for Entergy Texas includes $1.4 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 June 30, 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	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 June 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.075% $12.6 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 1.95% $59.5 (b) System Energy VIE May 2019 $120 2.075% $99.6 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) Commercial paper, classified as a current liability.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 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 June 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,783,804 $14,556,026 Entergy Arkansas $2,830,658 $2,835,020 Entergy Louisiana $5,410,218 $5,859,090 Entergy Mississippi $1,091,938 $1,153,791 Entergy New Orleans $459,095 $466,368 Entergy Texas $1,539,889 $1,704,985 System Energy $550,926 $543,935 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 million at Entergy Arkansas, and 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 June 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2016 Letters of Credit Outstanding as of June 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.71% $— $— Entergy Arkansas August 2020 $150 million (c) 1.71% $— $— Entergy Louisiana August 2020 $350 million (d) 1.71% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 1.96% $— $— Entergy Mississippi May 2017 $35 million (e) 1.96% $— $— Entergy Mississippi May 2017 $20 million (e) 1.96% $— $— Entergy Mississippi May 2017 $10 million (e) 1.96% $— $— Entergy New Orleans November 2018 $25 million (f) 2.21% $— $— Entergy Texas August 2020 $150 million (g) 1.96% $— $1.3 million (a) The interest rate is the rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $59.1 million Entergy Mississippi $40 million 0.70% $26.7 million Entergy New Orleans $15 million 0.75% $13.3 million Entergy Texas $50 million 0.70% $14.4 million (a) The amount for Entergy Texas includes $1.4 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 June 30, 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	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 June 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.075% $12.6 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 1.95% $59.5 (b) System Energy VIE May 2019 $120 2.075% $99.6 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) Commercial paper, classified as a current liability.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 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 June 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,783,804 $14,556,026 Entergy Arkansas $2,830,658 $2,835,020 Entergy Louisiana $5,410,218 $5,859,090 Entergy Mississippi $1,091,938 $1,153,791 Entergy New Orleans $459,095 $466,368 Entergy Texas $1,539,889 $1,704,985 System Energy $550,926 $543,935 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 million at Entergy Arkansas, and 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 June 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2016 Letters of Credit Outstanding as of June 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.71% $— $— Entergy Arkansas August 2020 $150 million (c) 1.71% $— $— Entergy Louisiana August 2020 $350 million (d) 1.71% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 1.96% $— $— Entergy Mississippi May 2017 $35 million (e) 1.96% $— $— Entergy Mississippi May 2017 $20 million (e) 1.96% $— $— Entergy Mississippi May 2017 $10 million (e) 1.96% $— $— Entergy New Orleans November 2018 $25 million (f) 2.21% $— $— Entergy Texas August 2020 $150 million (g) 1.96% $— $1.3 million (a) The interest rate is the rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $59.1 million Entergy Mississippi $40 million 0.70% $26.7 million Entergy New Orleans $15 million 0.75% $13.3 million Entergy Texas $50 million 0.70% $14.4 million (a) The amount for Entergy Texas includes $1.4 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 June 30, 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 June 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,783,804 $14,556,026 Entergy Arkansas $2,830,658 $2,835,020 Entergy Louisiana $5,410,218 $5,859,090 Entergy Mississippi $1,091,938 $1,153,791 Entergy New Orleans $459,095 $466,368 Entergy Texas $1,539,889 $1,704,985 System Energy $550,926 $543,935 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 million at Entergy Arkansas, and 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 June 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2016 Letters of Credit Outstanding as of June 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.71% $— $— Entergy Arkansas August 2020 $150 million (c) 1.71% $— $— Entergy Louisiana August 2020 $350 million (d) 1.71% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 1.96% $— $— Entergy Mississippi May 2017 $35 million (e) 1.96% $— $— Entergy Mississippi May 2017 $20 million (e) 1.96% $— $— Entergy Mississippi May 2017 $10 million (e) 1.96% $— $— Entergy New Orleans November 2018 $25 million (f) 2.21% $— $— Entergy Texas August 2020 $150 million (g) 1.96% $— $1.3 million (a) The interest rate is the rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $59.1 million Entergy Mississippi $40 million 0.70% $26.7 million Entergy New Orleans $15 million 0.75% $13.3 million Entergy Texas $50 million 0.70% $14.4 million (a) The amount for Entergy Texas includes $1.4 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 June 30, 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 June 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,783,804 $14,556,026 Entergy Arkansas $2,830,658 $2,835,020 Entergy Louisiana $5,410,218 $5,859,090 Entergy Mississippi $1,091,938 $1,153,791 Entergy New Orleans $459,095 $466,368 Entergy Texas $1,539,889 $1,704,985 System Energy $550,926 $543,935 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 million at Entergy Arkansas, and 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 June 30, 2016 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2016 Letters of Credit Outstanding as of June 30, 2016 Entergy Arkansas April 2017 $20 million (b) 1.71% $— $— Entergy Arkansas August 2020 $150 million (c) 1.71% $— $— Entergy Louisiana August 2020 $350 million (d) 1.71% $— $6.4 million Entergy Mississippi May 2017 $37.5 million (e) 1.96% $— $— Entergy Mississippi May 2017 $35 million (e) 1.96% $— $— Entergy Mississippi May 2017 $20 million (e) 1.96% $— $— Entergy Mississippi May 2017 $10 million (e) 1.96% $— $— Entergy New Orleans November 2018 $25 million (f) 2.21% $— $— Entergy Texas August 2020 $150 million (g) 1.96% $— $1.3 million (a) The interest rate is the rate as of June 30, 2016 that would most likely apply to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility. (d) The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility. (e) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. (f) The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility. (g) The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2016 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2016 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $59.1 million Entergy Mississippi $40 million 0.70% $26.7 million Entergy New Orleans $15 million 0.75% $13.3 million Entergy Texas $50 million 0.70% $14.4 million (a) The amount for Entergy Texas includes $1.4 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 June 30, 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 June 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,783,804 $14,556,026 Entergy Arkansas $2,830,658 $2,835,020 Entergy Louisiana $5,410,218 $5,859,090 Entergy Mississippi $1,091,938 $1,153,791 Entergy New Orleans $459,095 $466,368 Entergy Texas $1,539,889 $1,704,985 System Energy $550,926 $543,935 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 million at Entergy Arkansas, and 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 June 30, 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	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 June 30, 2016 : Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2016 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.075% $12.6 (b) Entergy Louisiana River Bend VIE May 2019 $105 n/a $— Entergy Louisiana Waterford VIE May 2019 $85 1.95% $59.5 (b) System Energy VIE May 2019 $120 2.075% $99.6 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) Commercial paper, classified as a current liability.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 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 June 30, 2016 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $13,783,804 $14,556,026 Entergy Arkansas $2,830,658 $2,835,020 Entergy Louisiana $5,410,218 $5,859,090 Entergy Mississippi $1,091,938 $1,153,791 Entergy New Orleans $459,095 $466,368 Entergy Texas $1,539,889 $1,704,985 System Energy $550,926 $543,935 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 million at Entergy Arkansas, and 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]	6 Months Ended
	Jun. 30, 2016
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Financial Information For Stock Options	The following table includes financial information for outstanding stock options for the three months ended June 30, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $1.1 $1.0 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 The following table includes financial information for outstanding stock options for the six months ended June 30, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $2.2 $2.1 Tax benefit recognized in Entergy’s net income $0.8 $0.8 Compensation cost capitalized as part of fixed assets and inventory $0.4 $0.4
Financial Information For Restricted Stock	The following table includes financial information for other outstanding equity awards for the three months ended June 30, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $8.5 $8.0 Tax benefit recognized in Entergy’s net income $3.3 $3.1 Compensation cost capitalized as part of fixed assets and inventory $1.9 $1.6 The following table includes financial information for other outstanding equity awards for the six months ended June 30, 2016 and 2015 : 2016 2015 (In Millions) Compensation expense included in Entergy’s net income $16.9 $16.1 Tax benefit recognized in Entergy’s net income $6.5 $6.2 Compensation cost capitalized as part of fixed assets and inventory $3.7 $3.1

Retirement And Other Postreti26

Retirement And Other Postretirement Benefits (Tables)	6 Months Ended
	Jun. 30, 2016
Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Reclassification out of Accumulated Other Comprehensive Income, amortization	Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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 ) (632 ) (15,177 ) ($12,752 ) $5,675 ($745 ) ($7,822 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (5 ) (1,573 ) ($836 ) $1,215 ($5 ) $374 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($6 ) ($669 ) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($540 ) $15,476 ($226 ) $14,710 Amortization of loss (24,964 ) (4,126 ) (1,262 ) (30,352 ) ($25,504 ) $11,350 ($1,488 ) ($15,642 ) Entergy Louisiana Amortization of prior service credit $— $3,894 $— $3,894 Amortization of loss (1,672 ) (1,464 ) (6 ) (3,142 ) ($1,672 ) $2,430 ($6 ) $752 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($778 ) $12,964 ($215 ) $11,971 Amortization of loss (25,254 ) (8,818 ) (1,104 ) (35,176 ) ($26,032 ) $4,146 ($1,319 ) ($23,205 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $3,734 ($1 ) $3,733 Amortization of loss (1,502 ) (3,558 ) (10 ) (5,070 ) ($1,502 ) $176 ($11 ) ($1,337 )
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 second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $35,811 $43,762 Interest cost on projected benefit obligation 65,403 75,694 Expected return on assets (97,366 ) (98,655 ) Amortization of prior service cost 270 390 Amortization of loss 48,824 58,981 Net pension costs $52,942 $80,172 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $71,622 $87,524 Interest cost on projected benefit obligation 130,806 151,388 Expected return on assets (194,732 ) (197,310 ) Amortization of prior service cost 540 780 Amortization of loss 97,648 117,962 Special termination benefit — 76 Net pension costs $105,884 $160,420
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 second quarters of 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $8,073 $11,326 Interest cost on accumulated postretirement benefit obligation (APBO) 14,083 17,984 Expected return on assets (10,455 ) (11,344 ) Amortization of prior service credit (11,373 ) (9,320 ) Amortization of loss 4,554 7,893 Net other postretirement benefit cost $4,882 $16,539 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2016 and 2015, included the following components: 2016 2015 (In Thousands) Service cost - benefits earned during the period $16,146 $22,652 Interest cost on accumulated postretirement benefit obligation (APBO) 28,166 35,968 Expected return on assets (20,910 ) (22,688 ) Amortization of prior service credit (22,746 ) (18,640 ) Amortization of loss 9,108 15,786 Net other postretirement benefit cost $9,764 $33,078
Entergy Arkansas [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,362 $14,098 $3,124 $1,312 $2,832 $3,132 Interest cost on projected benefit obligation 26,110 29,740 7,622 3,628 7,114 5,984 Expected return on assets (39,544 ) (44,192 ) (11,962 ) (5,374 ) (12,124 ) (8,918 ) Amortization of loss 21,872 23,892 5,970 3,230 4,680 5,208 Net pension cost $18,800 $23,538 $4,754 $2,796 $2,502 $5,406 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $13,322 $17,198 $3,964 $1,698 $3,290 $3,914 Interest cost on projected benefit obligation 30,942 34,734 9,004 4,216 8,708 6,986 Expected return on assets (40,052 ) (45,402 ) (12,210 ) (5,450 ) (12,444 ) (9,136 ) Amortization of loss 27,128 29,902 7,448 4,026 6,476 6,528 Net pension cost $31,340 $36,432 $8,206 $4,490 $6,030 $8,292
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of June 30, 2016 , Entergy had contributed $169.8 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 June 2016 $36,549 $37,319 $8,919 $4,680 $6,999 $8,891 Remaining estimated pension contributions to be made in 2016 $46,282 $46,590 $10,994 $6,014 $8,771 $11,315
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 second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,956 $3,738 $772 $312 $796 $668 Interest cost on APBO 4,648 6,520 1,418 896 2,078 1,058 Expected return on assets (8,928 ) — (2,758 ) (2,308 ) (4,788 ) (1,628 ) Amortization of prior service credit (2,736 ) (3,894 ) (468 ) (372 ) (1,362 ) (786 ) Amortization of loss 2,128 1,464 446 74 1,074 574 Net other postretirement benefit cost ($2,932 ) $7,828 ($590 ) ($1,398 ) ($2,202 ) ($114 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $3,478 $4,948 $1,014 $410 $1,000 $940 Interest cost on APBO 6,260 8,156 1,718 1,304 2,684 1,256 Expected return on assets (9,596 ) — (3,084 ) (2,402 ) (5,176 ) (1,822 ) Amortization of prior service credit (1,220 ) (3,734 ) (458 ) (354 ) (1,362 ) (732 ) Amortization of loss 2,678 3,560 430 236 1,370 600 Net other postretirement benefit cost $1,600 $12,930 ($380 ) ($806 ) ($1,484 ) $242
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 second quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost second quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost second quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost six months ended June 30, 2016 $212 $118 $118 $32 $254 Non-qualified pension cost six months ended June 30, 2015 $226 $136 $118 $32 $298
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Reclassification out of Accumulated Other Comprehensive Income, amortization	Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 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 ) (632 ) (15,177 ) ($12,752 ) $5,675 ($745 ) ($7,822 ) Entergy Louisiana Amortization of prior service credit $— $1,947 $— $1,947 Amortization of loss (836 ) (732 ) (5 ) (1,573 ) ($836 ) $1,215 ($5 ) $374 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($389 ) $6,482 ($108 ) $5,985 Amortization of loss (12,627 ) (4,409 ) (552 ) (17,588 ) ($13,016 ) $2,073 ($660 ) ($11,603 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $1,867 ($1 ) $1,866 Amortization of loss (751 ) (1,779 ) (5 ) (2,535 ) ($751 ) $88 ($6 ) ($669 ) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2016 and 2015: 2016 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($540 ) $15,476 ($226 ) $14,710 Amortization of loss (24,964 ) (4,126 ) (1,262 ) (30,352 ) ($25,504 ) $11,350 ($1,488 ) ($15,642 ) Entergy Louisiana Amortization of prior service credit $— $3,894 $— $3,894 Amortization of loss (1,672 ) (1,464 ) (6 ) (3,142 ) ($1,672 ) $2,430 ($6 ) $752 2015 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($778 ) $12,964 ($215 ) $11,971 Amortization of loss (25,254 ) (8,818 ) (1,104 ) (35,176 ) ($26,032 ) $4,146 ($1,319 ) ($23,205 ) Entergy Louisiana Amortization of prior service (cost)/credit $— $3,734 ($1 ) $3,733 Amortization of loss (1,502 ) (3,558 ) (10 ) (5,070 ) ($1,502 ) $176 ($11 ) ($1,337 )
Entergy Louisiana [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,362 $14,098 $3,124 $1,312 $2,832 $3,132 Interest cost on projected benefit obligation 26,110 29,740 7,622 3,628 7,114 5,984 Expected return on assets (39,544 ) (44,192 ) (11,962 ) (5,374 ) (12,124 ) (8,918 ) Amortization of loss 21,872 23,892 5,970 3,230 4,680 5,208 Net pension cost $18,800 $23,538 $4,754 $2,796 $2,502 $5,406 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $13,322 $17,198 $3,964 $1,698 $3,290 $3,914 Interest cost on projected benefit obligation 30,942 34,734 9,004 4,216 8,708 6,986 Expected return on assets (40,052 ) (45,402 ) (12,210 ) (5,450 ) (12,444 ) (9,136 ) Amortization of loss 27,128 29,902 7,448 4,026 6,476 6,528 Net pension cost $31,340 $36,432 $8,206 $4,490 $6,030 $8,292
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of June 30, 2016 , Entergy had contributed $169.8 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 June 2016 $36,549 $37,319 $8,919 $4,680 $6,999 $8,891 Remaining estimated pension contributions to be made in 2016 $46,282 $46,590 $10,994 $6,014 $8,771 $11,315
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 second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,956 $3,738 $772 $312 $796 $668 Interest cost on APBO 4,648 6,520 1,418 896 2,078 1,058 Expected return on assets (8,928 ) — (2,758 ) (2,308 ) (4,788 ) (1,628 ) Amortization of prior service credit (2,736 ) (3,894 ) (468 ) (372 ) (1,362 ) (786 ) Amortization of loss 2,128 1,464 446 74 1,074 574 Net other postretirement benefit cost ($2,932 ) $7,828 ($590 ) ($1,398 ) ($2,202 ) ($114 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $3,478 $4,948 $1,014 $410 $1,000 $940 Interest cost on APBO 6,260 8,156 1,718 1,304 2,684 1,256 Expected return on assets (9,596 ) — (3,084 ) (2,402 ) (5,176 ) (1,822 ) Amortization of prior service credit (1,220 ) (3,734 ) (458 ) (354 ) (1,362 ) (732 ) Amortization of loss 2,678 3,560 430 236 1,370 600 Net other postretirement benefit cost $1,600 $12,930 ($380 ) ($806 ) ($1,484 ) $242
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 second quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost second quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost second quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost six months ended June 30, 2016 $212 $118 $118 $32 $254 Non-qualified pension cost six months ended June 30, 2015 $226 $136 $118 $32 $298
Entergy Mississippi [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,362 $14,098 $3,124 $1,312 $2,832 $3,132 Interest cost on projected benefit obligation 26,110 29,740 7,622 3,628 7,114 5,984 Expected return on assets (39,544 ) (44,192 ) (11,962 ) (5,374 ) (12,124 ) (8,918 ) Amortization of loss 21,872 23,892 5,970 3,230 4,680 5,208 Net pension cost $18,800 $23,538 $4,754 $2,796 $2,502 $5,406 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $13,322 $17,198 $3,964 $1,698 $3,290 $3,914 Interest cost on projected benefit obligation 30,942 34,734 9,004 4,216 8,708 6,986 Expected return on assets (40,052 ) (45,402 ) (12,210 ) (5,450 ) (12,444 ) (9,136 ) Amortization of loss 27,128 29,902 7,448 4,026 6,476 6,528 Net pension cost $31,340 $36,432 $8,206 $4,490 $6,030 $8,292
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of June 30, 2016 , Entergy had contributed $169.8 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 June 2016 $36,549 $37,319 $8,919 $4,680 $6,999 $8,891 Remaining estimated pension contributions to be made in 2016 $46,282 $46,590 $10,994 $6,014 $8,771 $11,315
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 second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,956 $3,738 $772 $312 $796 $668 Interest cost on APBO 4,648 6,520 1,418 896 2,078 1,058 Expected return on assets (8,928 ) — (2,758 ) (2,308 ) (4,788 ) (1,628 ) Amortization of prior service credit (2,736 ) (3,894 ) (468 ) (372 ) (1,362 ) (786 ) Amortization of loss 2,128 1,464 446 74 1,074 574 Net other postretirement benefit cost ($2,932 ) $7,828 ($590 ) ($1,398 ) ($2,202 ) ($114 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $3,478 $4,948 $1,014 $410 $1,000 $940 Interest cost on APBO 6,260 8,156 1,718 1,304 2,684 1,256 Expected return on assets (9,596 ) — (3,084 ) (2,402 ) (5,176 ) (1,822 ) Amortization of prior service credit (1,220 ) (3,734 ) (458 ) (354 ) (1,362 ) (732 ) Amortization of loss 2,678 3,560 430 236 1,370 600 Net other postretirement benefit cost $1,600 $12,930 ($380 ) ($806 ) ($1,484 ) $242
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 second quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost second quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost second quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost six months ended June 30, 2016 $212 $118 $118 $32 $254 Non-qualified pension cost six months ended June 30, 2015 $226 $136 $118 $32 $298
Entergy New Orleans [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,362 $14,098 $3,124 $1,312 $2,832 $3,132 Interest cost on projected benefit obligation 26,110 29,740 7,622 3,628 7,114 5,984 Expected return on assets (39,544 ) (44,192 ) (11,962 ) (5,374 ) (12,124 ) (8,918 ) Amortization of loss 21,872 23,892 5,970 3,230 4,680 5,208 Net pension cost $18,800 $23,538 $4,754 $2,796 $2,502 $5,406 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $13,322 $17,198 $3,964 $1,698 $3,290 $3,914 Interest cost on projected benefit obligation 30,942 34,734 9,004 4,216 8,708 6,986 Expected return on assets (40,052 ) (45,402 ) (12,210 ) (5,450 ) (12,444 ) (9,136 ) Amortization of loss 27,128 29,902 7,448 4,026 6,476 6,528 Net pension cost $31,340 $36,432 $8,206 $4,490 $6,030 $8,292
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of June 30, 2016 , Entergy had contributed $169.8 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 June 2016 $36,549 $37,319 $8,919 $4,680 $6,999 $8,891 Remaining estimated pension contributions to be made in 2016 $46,282 $46,590 $10,994 $6,014 $8,771 $11,315
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 second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,956 $3,738 $772 $312 $796 $668 Interest cost on APBO 4,648 6,520 1,418 896 2,078 1,058 Expected return on assets (8,928 ) — (2,758 ) (2,308 ) (4,788 ) (1,628 ) Amortization of prior service credit (2,736 ) (3,894 ) (468 ) (372 ) (1,362 ) (786 ) Amortization of loss 2,128 1,464 446 74 1,074 574 Net other postretirement benefit cost ($2,932 ) $7,828 ($590 ) ($1,398 ) ($2,202 ) ($114 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $3,478 $4,948 $1,014 $410 $1,000 $940 Interest cost on APBO 6,260 8,156 1,718 1,304 2,684 1,256 Expected return on assets (9,596 ) — (3,084 ) (2,402 ) (5,176 ) (1,822 ) Amortization of prior service credit (1,220 ) (3,734 ) (458 ) (354 ) (1,362 ) (732 ) Amortization of loss 2,678 3,560 430 236 1,370 600 Net other postretirement benefit cost $1,600 $12,930 ($380 ) ($806 ) ($1,484 ) $242
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 second quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost second quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost second quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost six months ended June 30, 2016 $212 $118 $118 $32 $254 Non-qualified pension cost six months ended June 30, 2015 $226 $136 $118 $32 $298
Entergy Texas [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,362 $14,098 $3,124 $1,312 $2,832 $3,132 Interest cost on projected benefit obligation 26,110 29,740 7,622 3,628 7,114 5,984 Expected return on assets (39,544 ) (44,192 ) (11,962 ) (5,374 ) (12,124 ) (8,918 ) Amortization of loss 21,872 23,892 5,970 3,230 4,680 5,208 Net pension cost $18,800 $23,538 $4,754 $2,796 $2,502 $5,406 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $13,322 $17,198 $3,964 $1,698 $3,290 $3,914 Interest cost on projected benefit obligation 30,942 34,734 9,004 4,216 8,708 6,986 Expected return on assets (40,052 ) (45,402 ) (12,210 ) (5,450 ) (12,444 ) (9,136 ) Amortization of loss 27,128 29,902 7,448 4,026 6,476 6,528 Net pension cost $31,340 $36,432 $8,206 $4,490 $6,030 $8,292
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of June 30, 2016 , Entergy had contributed $169.8 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 June 2016 $36,549 $37,319 $8,919 $4,680 $6,999 $8,891 Remaining estimated pension contributions to be made in 2016 $46,282 $46,590 $10,994 $6,014 $8,771 $11,315
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 second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,956 $3,738 $772 $312 $796 $668 Interest cost on APBO 4,648 6,520 1,418 896 2,078 1,058 Expected return on assets (8,928 ) — (2,758 ) (2,308 ) (4,788 ) (1,628 ) Amortization of prior service credit (2,736 ) (3,894 ) (468 ) (372 ) (1,362 ) (786 ) Amortization of loss 2,128 1,464 446 74 1,074 574 Net other postretirement benefit cost ($2,932 ) $7,828 ($590 ) ($1,398 ) ($2,202 ) ($114 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $3,478 $4,948 $1,014 $410 $1,000 $940 Interest cost on APBO 6,260 8,156 1,718 1,304 2,684 1,256 Expected return on assets (9,596 ) — (3,084 ) (2,402 ) (5,176 ) (1,822 ) Amortization of prior service credit (1,220 ) (3,734 ) (458 ) (354 ) (1,362 ) (732 ) Amortization of loss 2,678 3,560 430 236 1,370 600 Net other postretirement benefit cost $1,600 $12,930 ($380 ) ($806 ) ($1,484 ) $242
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 second quarters of 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost second quarter 2016 $106 $59 $59 $16 $127 Non-qualified pension cost second quarter 2015 $113 $68 $59 $16 $149 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2016 and 2015: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Non-qualified pension cost six months ended June 30, 2016 $212 $118 $118 $32 $254 Non-qualified pension cost six months ended June 30, 2015 $226 $136 $118 $32 $298
System Energy [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,661 $8,599 $1,982 $849 $1,645 $1,957 Interest cost on projected benefit obligation 15,471 17,367 4,502 2,108 4,354 3,493 Expected return on assets (20,026 ) (22,701 ) (6,105 ) (2,725 ) (6,222 ) (4,568 ) Amortization of loss 13,564 14,951 3,724 2,013 3,238 3,264 Net pension cost $15,670 $18,216 $4,103 $2,245 $3,015 $4,146 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,362 $14,098 $3,124 $1,312 $2,832 $3,132 Interest cost on projected benefit obligation 26,110 29,740 7,622 3,628 7,114 5,984 Expected return on assets (39,544 ) (44,192 ) (11,962 ) (5,374 ) (12,124 ) (8,918 ) Amortization of loss 21,872 23,892 5,970 3,230 4,680 5,208 Net pension cost $18,800 $23,538 $4,754 $2,796 $2,502 $5,406 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $13,322 $17,198 $3,964 $1,698 $3,290 $3,914 Interest cost on projected benefit obligation 30,942 34,734 9,004 4,216 8,708 6,986 Expected return on assets (40,052 ) (45,402 ) (12,210 ) (5,450 ) (12,444 ) (9,136 ) Amortization of loss 27,128 29,902 7,448 4,026 6,476 6,528 Net pension cost $31,340 $36,432 $8,206 $4,490 $6,030 $8,292
Expected Employer Contributions	Based on current assumptions, Entergy expects to contribute $387.5 million to its qualified pension plans in 2016. As of June 30, 2016 , Entergy had contributed $169.8 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 June 2016 $36,549 $37,319 $8,919 $4,680 $6,999 $8,891 Remaining estimated pension contributions to be made in 2016 $46,282 $46,590 $10,994 $6,014 $8,771 $11,315
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 second quarters of 2016 and 2015, included the following components: 2016 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,739 $2,474 $507 $205 $500 $470 Interest cost on APBO 3,130 4,078 859 652 1,342 628 Expected return on assets (4,798 ) — (1,542 ) (1,201 ) (2,588 ) (911 ) Amortization of prior service credit (610 ) (1,867 ) (229 ) (177 ) (681 ) (366 ) Amortization of loss 1,339 1,780 215 118 685 300 Net other postretirement benefit cost $800 $6,465 ($190 ) ($403 ) ($742 ) $121 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2016 and 2015, included the following components: 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,956 $3,738 $772 $312 $796 $668 Interest cost on APBO 4,648 6,520 1,418 896 2,078 1,058 Expected return on assets (8,928 ) — (2,758 ) (2,308 ) (4,788 ) (1,628 ) Amortization of prior service credit (2,736 ) (3,894 ) (468 ) (372 ) (1,362 ) (786 ) Amortization of loss 2,128 1,464 446 74 1,074 574 Net other postretirement benefit cost ($2,932 ) $7,828 ($590 ) ($1,398 ) ($2,202 ) ($114 ) 2015 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $3,478 $4,948 $1,014 $410 $1,000 $940 Interest cost on APBO 6,260 8,156 1,718 1,304 2,684 1,256 Expected return on assets (9,596 ) — (3,084 ) (2,402 ) (5,176 ) (1,822 ) Amortization of prior service credit (1,220 ) (3,734 ) (458 ) (354 ) (1,362 ) (732 ) Amortization of loss 2,678 3,560 430 236 1,370 600 Net other postretirement benefit cost $1,600 $12,930 ($380 ) ($806 ) ($1,484 ) $242

Business Segment Information (T

Business Segment Information (Tables)	6 Months Ended
	Jun. 30, 2016
Parent Company [Member]
Segment Financial Information	Entergy’s segment financial information for the second quarters of 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $2,118,478 $344,110 $— ($26 ) $2,462,562 Income taxes ($3,785 ) ($235,055 ) ($10,133 ) $— ($248,973 ) Consolidated net income (loss) $380,317 $250,874 ($26,703 ) ($31,898 ) $572,590 2015 Operating revenues $2,273,945 $439,306 $— ($20 ) $2,713,231 Income taxes $117,798 ($3,300 ) ($14,717 ) $— $99,781 Consolidated net income (loss) $204,035 ($3,545 ) ($14,870 ) ($31,898 ) $153,722 Entergy’s segment financial information for the six months ended June 30, 2016 and 2015 is as follows: Utility Entergy Wholesale Commodities* All Other Eliminations Entergy (In Thousands) 2016 Operating revenues $4,206,272 $866,189 $— ($46 ) $5,072,415 Income taxes $104,051 ($182,741 ) ($30,337 ) $— ($109,027 ) Consolidated net income (loss) $579,968 $330,430 ($38,769 ) ($63,797 ) $807,832 Total assets as of June 30, 2016 $39,841,100 $7,913,442 $1,211,715 ($3,089,215 ) $45,877,042 2015 Operating revenues $4,551,455 $1,081,896 $— ($30 ) $5,633,321 Income taxes $209,048 $66,891 ($25,687 ) $— $250,252 Consolidated net income (loss) $431,786 $119,887 ($31,224 ) ($63,798 ) $456,651 Total assets as of December 31, 2015 $38,356,906 $8,210,183 ($461,505 ) ($1,457,903 ) $44,647,681 Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.

Risk Management And Fair Valu28

Risk Management And Fair Values (Tables)	6 Months Ended
	Jun. 30, 2016
Fair Values Of Derivative Instruments	The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of June 30, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($9) $41 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $7 ($7) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $7 ($5) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $50 ($22) $28 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $8 $— $8 Entergy Wholesale Commodities Natural gas swaps Prepayments and other $16 $— $16 Utility FTRs Prepayments and other $47 ($1) $46 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $31 ($24) $7 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $3 ($1) $2 Entergy Wholesale Commodities 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 June 30, 2016 and 2015 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 2015 Electricity swaps and options $137 Competitive businesses operating revenues $78 (a) Before taxes of $16 million and $27 million for the three months ended June 30, 2016 and 2015, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in other comprehensive income Income Statement location Amount of gain reclassified from AOCI into income (a) (In Millions) (In Millions) 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 2015 Electricity swaps and options $105 Competitive businesses operating revenues $91 (a) Before taxes of $70 million and $32 million for the six months ended June 30, 2016 and 2015, respectively
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the three months ended June 30, 2016 and 2015 are as follows: Instrument Amount of loss recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($6) FTRs $— Purchased power expense (b) $38 Electricity swaps and options de-designated as hedged items ($10) Competitive business operating revenues ($6) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $3 FTRs $— Purchased power expense (b) $46 Electricity swaps and options de-designated as hedged items ($3) Competitive business operating revenues ($5) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated statements of operations for the six months ended June 30, 2016 and 2015 are as follows: Instrument Amount of gain recognized in AOCI Income Statement Amount of gain (loss) (In Millions) (In Millions) 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) FTRs $— Purchased power expense (b) $59 Electricity swaps and options de-designated as hedged items $15 Competitive business operating revenues ($9) 2015 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) FTRs $— Purchased power expense (b) $79 Electricity swaps and options de-designated as hedged items $1 Competitive business operating revenues ($39) (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 June 30, 2016 and December 31, 2015 . The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect their placement within the fair value hierarchy levels. 2016 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $893 $— $— $893 Decommissioning trust funds (a): Equity securities 464 — — 464 Debt securities 1,053 1,220 — 2,273 Common trusts (b) 2,819 Power contracts — — 77 77 Securitization recovery trust account 37 — — 37 Escrow accounts 433 — — 433 Gas hedge contracts 16 — — 16 FTRs — — 46 46 $2,896 $1,220 $123 $7,058 Liabilities: Power contracts $— $— $11 $11 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 June 30, 2016 and 2015 : 2016 2015 Power Contracts FTRs Power Contracts FTRs (In Millions) Balance as of April 1, $183 $9 $145 $15 Total gains (losses) for the period (a) Included in earnings (9 ) — 22 — Included in OCI (53 ) — 131 — Included as a regulatory liability/asset — 20 — 18 Issuances of FTRs — 55 — 80 Purchases — — 4 — Settlements (55 ) (38 ) (98 ) (46 ) Balance as of June 30, $66 $46 $204 $67 (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 June 30, 2016 and ($1) million for the three months ended June 30, 2015. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2016 and 2015 : 2016 2015 Power Contracts FTRs Power Contracts FTRs (In Millions) Balance as of January 1, $189 $23 $215 $47 Total gains (losses) for the period (a) Included in earnings (9 ) — (13 ) (1 ) Included in OCI 86 — 105 — Included as a regulatory liability/asset — 27 — 20 Issuances of FTRs — 55 — 80 Purchases — — 14 — Settlements (200 ) (59 ) (117 ) (79 ) Balance as of June 30, $66 $46 $204 $67 (a) For the six months ended June 30, 2016, there is no change in unrealized gains or losses included in earnings for derivatives held at the end of the reporting period. Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($7) million for the six months ended June 30, 2015
Fair Value Inputs Liabilities Quantitative Information	The following table sets forth a description of the types of transactions classified as Level 3 in the fair value hierarchy and significant unobservable inputs to each which cause that classification as of June 30, 2016 : Transaction Type Fair Value as of June 30, 2016 Significant Unobservable Inputs Range from Average % Effect on Fair Value (In Millions) (In Millions) Power contracts - electricity swaps $61 Unit contingent discount +/- 3% $2 Power contracts - electricity options $5 Implied volatility +/- 34% $3
Entergy Arkansas [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $12.8 Entergy Louisiana Natural gas swaps Prepayments and other $2.7 Entergy Mississippi FTRs Prepayments and other $14.0 Entergy Arkansas FTRs Prepayments and other $16.2 Entergy Louisiana FTRs Prepayments and other $5.6 Entergy Mississippi FTRs Prepayments and other $2.0 Entergy New Orleans FTRs Prepayments and other $8.0 Entergy Texas 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 $1.4 million posted by Entergy Texas as of June 30, 2016. No cash collateral was required to be posted as of June 30, 2016 and December 31, 2015, respectively.
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy Mississippi FTRs Purchased power expense $5.5 (b) Entergy Arkansas FTRs Purchased power expense $21.6 (b) Entergy Louisiana FTRs Purchased power expense $3.6 (b) Entergy Mississippi FTRs Purchased power expense $1.4 (b) Entergy New Orleans FTRs Purchased power expense $5.4 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $2.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.6 (a) Entergy Mississippi FTRs Purchased power expense $19.6 (b) Entergy Arkansas FTRs Purchased power expense $17.3 (b) Entergy Louisiana FTRs Purchased power expense $3.9 (b) Entergy Mississippi FTRs Purchased power expense $4.5 (b) Entergy New Orleans FTRs Purchased power expense $1.2 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($24.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.0) (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 $13.3 (b) Entergy Arkansas FTRs Purchased power expense $32.1 (b) Entergy Louisiana FTRs Purchased power expense $4.4 (b) Entergy Mississippi FTRs Purchased power expense $1.9 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.5) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.4) (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 $34.7 (b) Entergy Arkansas FTRs Purchased power expense $31.7 (b) Entergy Louisiana FTRs Purchased power expense $7.2 (b) Entergy Mississippi FTRs Purchased power expense $6.0 (b) Entergy New Orleans FTRs Purchased power expense ($0.2) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of 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 $11.3 $— $— $11.3 Decommissioning trust funds (a): Equity securities 16.8 — — 16.8 Debt securities 97.4 207.8 — 305.2 Common trusts (b) 480.8 Securitization recovery trust account 3.2 — — 3.2 Escrow accounts 7.1 — — 7.1 FTRs — — 14.0 14.0 $135.8 $207.8 $14.0 $838.4 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 June 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of April 1, $3.7 $3.3 $0.9 $0.6 $0.9 Issuances of FTRs 18.8 18.1 5.9 2.8 9.3 Gains (losses) included as a regulatory liability/asset (3.0 ) 16.4 2.4 — 3.2 Settlements (5.5 ) (21.6 ) (3.6 ) (1.4 ) (5.4 ) Balance as of June 30, $14.0 $16.2 $5.6 $2.0 $8.0 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2015 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $0.6 $8.8 $0.9 $1.4 $3.4 Issuances of FTRs 7.0 48.2 5.4 7.3 11.4 Gains (losses) included as a regulatory liability/asset 21.1 (2.4 ) 2.5 2.5 (5.7 ) Settlements (19.6 ) (17.3 ) (3.9 ) (4.5 ) (1.2 ) Balance as of June 30, $9.1 $37.3 $4.9 $6.7 $7.9 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 six months ended June 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $7.9 $8.5 $2.4 $1.5 $2.2 Issuances of FTRs 18.8 18.1 5.9 2.8 9.3 Gains (losses) included as a regulatory liability/asset 0.6 21.7 1.7 (0.4 ) 3.4 Settlements (13.3 ) (32.1 ) (4.4 ) (1.9 ) (6.9 ) Balance as of June 30, $14.0 $16.2 $5.6 $2.0 $8.0 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2015 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $0.7 $25.5 $3.4 $4.1 $12.3 Issuances of FTRs 7.0 48.2 5.4 7.3 11.4 Gains (losses) included as a regulatory liability/asset 36.1 (4.7 ) 3.3 1.3 (16.0 ) Settlements (34.7 ) (31.7 ) (7.2 ) (6.0 ) 0.2 Balance as of June 30, $9.1 $37.3 $4.9 $6.7 $7.9
Entergy Louisiana [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $12.8 Entergy Louisiana Natural gas swaps Prepayments and other $2.7 Entergy Mississippi FTRs Prepayments and other $14.0 Entergy Arkansas FTRs Prepayments and other $16.2 Entergy Louisiana FTRs Prepayments and other $5.6 Entergy Mississippi FTRs Prepayments and other $2.0 Entergy New Orleans FTRs Prepayments and other $8.0 Entergy Texas 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 $1.4 million posted by Entergy Texas as of June 30, 2016. No cash collateral was required to be posted as of June 30, 2016 and December 31, 2015, respectively.
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy Mississippi FTRs Purchased power expense $5.5 (b) Entergy Arkansas FTRs Purchased power expense $21.6 (b) Entergy Louisiana FTRs Purchased power expense $3.6 (b) Entergy Mississippi FTRs Purchased power expense $1.4 (b) Entergy New Orleans FTRs Purchased power expense $5.4 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $2.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.6 (a) Entergy Mississippi FTRs Purchased power expense $19.6 (b) Entergy Arkansas FTRs Purchased power expense $17.3 (b) Entergy Louisiana FTRs Purchased power expense $3.9 (b) Entergy Mississippi FTRs Purchased power expense $4.5 (b) Entergy New Orleans FTRs Purchased power expense $1.2 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($24.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.0) (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 $13.3 (b) Entergy Arkansas FTRs Purchased power expense $32.1 (b) Entergy Louisiana FTRs Purchased power expense $4.4 (b) Entergy Mississippi FTRs Purchased power expense $1.9 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.5) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.4) (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 $34.7 (b) Entergy Arkansas FTRs Purchased power expense $31.7 (b) Entergy Louisiana FTRs Purchased power expense $7.2 (b) Entergy Mississippi FTRs Purchased power expense $6.0 (b) Entergy New Orleans FTRs Purchased power expense ($0.2) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of 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 $50.1 $— $— $50.1 Decommissioning trust funds (a): Equity securities 6.9 — — 6.9 Debt securities 137.0 299.2 — 436.2 Common trusts (b) 651.7 Escrow accounts 305.2 — — 305.2 Securitization recovery trust account 3.0 — — 3.0 Gas hedge contracts 12.8 — — 12.8 FTRs — — 16.2 16.2 $515.0 $299.2 $16.2 $1,482.1 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 June 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of April 1, $3.7 $3.3 $0.9 $0.6 $0.9 Issuances of FTRs 18.8 18.1 5.9 2.8 9.3 Gains (losses) included as a regulatory liability/asset (3.0 ) 16.4 2.4 — 3.2 Settlements (5.5 ) (21.6 ) (3.6 ) (1.4 ) (5.4 ) Balance as of June 30, $14.0 $16.2 $5.6 $2.0 $8.0 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2015 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $0.6 $8.8 $0.9 $1.4 $3.4 Issuances of FTRs 7.0 48.2 5.4 7.3 11.4 Gains (losses) included as a regulatory liability/asset 21.1 (2.4 ) 2.5 2.5 (5.7 ) Settlements (19.6 ) (17.3 ) (3.9 ) (4.5 ) (1.2 ) Balance as of June 30, $9.1 $37.3 $4.9 $6.7 $7.9 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 six months ended June 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $7.9 $8.5 $2.4 $1.5 $2.2 Issuances of FTRs 18.8 18.1 5.9 2.8 9.3 Gains (losses) included as a regulatory liability/asset 0.6 21.7 1.7 (0.4 ) 3.4 Settlements (13.3 ) (32.1 ) (4.4 ) (1.9 ) (6.9 ) Balance as of June 30, $14.0 $16.2 $5.6 $2.0 $8.0 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2015 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $0.7 $25.5 $3.4 $4.1 $12.3 Issuances of FTRs 7.0 48.2 5.4 7.3 11.4 Gains (losses) included as a regulatory liability/asset 36.1 (4.7 ) 3.3 1.3 (16.0 ) Settlements (34.7 ) (31.7 ) (7.2 ) (6.0 ) 0.2 Balance as of June 30, $9.1 $37.3 $4.9 $6.7 $7.9
Entergy Mississippi [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $12.8 Entergy Louisiana Natural gas swaps Prepayments and other $2.7 Entergy Mississippi FTRs Prepayments and other $14.0 Entergy Arkansas FTRs Prepayments and other $16.2 Entergy Louisiana FTRs Prepayments and other $5.6 Entergy Mississippi FTRs Prepayments and other $2.0 Entergy New Orleans FTRs Prepayments and other $8.0 Entergy Texas 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 $1.4 million posted by Entergy Texas as of June 30, 2016. No cash collateral was required to be posted as of June 30, 2016 and December 31, 2015, respectively.
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy Mississippi FTRs Purchased power expense $5.5 (b) Entergy Arkansas FTRs Purchased power expense $21.6 (b) Entergy Louisiana FTRs Purchased power expense $3.6 (b) Entergy Mississippi FTRs Purchased power expense $1.4 (b) Entergy New Orleans FTRs Purchased power expense $5.4 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $2.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.6 (a) Entergy Mississippi FTRs Purchased power expense $19.6 (b) Entergy Arkansas FTRs Purchased power expense $17.3 (b) Entergy Louisiana FTRs Purchased power expense $3.9 (b) Entergy Mississippi FTRs Purchased power expense $4.5 (b) Entergy New Orleans FTRs Purchased power expense $1.2 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($24.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.0) (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 $13.3 (b) Entergy Arkansas FTRs Purchased power expense $32.1 (b) Entergy Louisiana FTRs Purchased power expense $4.4 (b) Entergy Mississippi FTRs Purchased power expense $1.9 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.5) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.4) (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 $34.7 (b) Entergy Arkansas FTRs Purchased power expense $31.7 (b) Entergy Louisiana FTRs Purchased power expense $7.2 (b) Entergy Mississippi FTRs Purchased power expense $6.0 (b) Entergy New Orleans FTRs Purchased power expense ($0.2) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of 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 $105.3 $— $— $105.3 Escrow accounts 31.8 — — 31.8 Gas hedge contracts 2.7 — — 2.7 FTRs — — 5.6 5.6 $139.8 $— $5.6 $145.4 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 June 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of April 1, $3.7 $3.3 $0.9 $0.6 $0.9 Issuances of FTRs 18.8 18.1 5.9 2.8 9.3 Gains (losses) included as a regulatory liability/asset (3.0 ) 16.4 2.4 — 3.2 Settlements (5.5 ) (21.6 ) (3.6 ) (1.4 ) (5.4 ) Balance as of June 30, $14.0 $16.2 $5.6 $2.0 $8.0 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2015 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $0.6 $8.8 $0.9 $1.4 $3.4 Issuances of FTRs 7.0 48.2 5.4 7.3 11.4 Gains (losses) included as a regulatory liability/asset 21.1 (2.4 ) 2.5 2.5 (5.7 ) Settlements (19.6 ) (17.3 ) (3.9 ) (4.5 ) (1.2 ) Balance as of June 30, $9.1 $37.3 $4.9 $6.7 $7.9 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 six months ended June 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $7.9 $8.5 $2.4 $1.5 $2.2 Issuances of FTRs 18.8 18.1 5.9 2.8 9.3 Gains (losses) included as a regulatory liability/asset 0.6 21.7 1.7 (0.4 ) 3.4 Settlements (13.3 ) (32.1 ) (4.4 ) (1.9 ) (6.9 ) Balance as of June 30, $14.0 $16.2 $5.6 $2.0 $8.0 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2015 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $0.7 $25.5 $3.4 $4.1 $12.3 Issuances of FTRs 7.0 48.2 5.4 7.3 11.4 Gains (losses) included as a regulatory liability/asset 36.1 (4.7 ) 3.3 1.3 (16.0 ) Settlements (34.7 ) (31.7 ) (7.2 ) (6.0 ) 0.2 Balance as of June 30, $9.1 $37.3 $4.9 $6.7 $7.9
Entergy New Orleans [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $12.8 Entergy Louisiana Natural gas swaps Prepayments and other $2.7 Entergy Mississippi FTRs Prepayments and other $14.0 Entergy Arkansas FTRs Prepayments and other $16.2 Entergy Louisiana FTRs Prepayments and other $5.6 Entergy Mississippi FTRs Prepayments and other $2.0 Entergy New Orleans FTRs Prepayments and other $8.0 Entergy Texas 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 $1.4 million posted by Entergy Texas as of June 30, 2016. No cash collateral was required to be posted as of June 30, 2016 and December 31, 2015, respectively.
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy Mississippi FTRs Purchased power expense $5.5 (b) Entergy Arkansas FTRs Purchased power expense $21.6 (b) Entergy Louisiana FTRs Purchased power expense $3.6 (b) Entergy Mississippi FTRs Purchased power expense $1.4 (b) Entergy New Orleans FTRs Purchased power expense $5.4 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $2.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.6 (a) Entergy Mississippi FTRs Purchased power expense $19.6 (b) Entergy Arkansas FTRs Purchased power expense $17.3 (b) Entergy Louisiana FTRs Purchased power expense $3.9 (b) Entergy Mississippi FTRs Purchased power expense $4.5 (b) Entergy New Orleans FTRs Purchased power expense $1.2 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($24.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.0) (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 $13.3 (b) Entergy Arkansas FTRs Purchased power expense $32.1 (b) Entergy Louisiana FTRs Purchased power expense $4.4 (b) Entergy Mississippi FTRs Purchased power expense $1.9 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.5) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.4) (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 $34.7 (b) Entergy Arkansas FTRs Purchased power expense $31.7 (b) Entergy Louisiana FTRs Purchased power expense $7.2 (b) Entergy Mississippi FTRs Purchased power expense $6.0 (b) Entergy New Orleans FTRs Purchased power expense ($0.2) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of 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 $23.4 $— $— $23.4 Securitization recovery trust account 1.3 — — 1.3 Escrow accounts 88.3 — — 88.3 FTRs — — 2.0 2.0 $113.0 $— $2.0 $115.0 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 June 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of April 1, $3.7 $3.3 $0.9 $0.6 $0.9 Issuances of FTRs 18.8 18.1 5.9 2.8 9.3 Gains (losses) included as a regulatory liability/asset (3.0 ) 16.4 2.4 — 3.2 Settlements (5.5 ) (21.6 ) (3.6 ) (1.4 ) (5.4 ) Balance as of June 30, $14.0 $16.2 $5.6 $2.0 $8.0 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2015 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $0.6 $8.8 $0.9 $1.4 $3.4 Issuances of FTRs 7.0 48.2 5.4 7.3 11.4 Gains (losses) included as a regulatory liability/asset 21.1 (2.4 ) 2.5 2.5 (5.7 ) Settlements (19.6 ) (17.3 ) (3.9 ) (4.5 ) (1.2 ) Balance as of June 30, $9.1 $37.3 $4.9 $6.7 $7.9 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 six months ended June 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $7.9 $8.5 $2.4 $1.5 $2.2 Issuances of FTRs 18.8 18.1 5.9 2.8 9.3 Gains (losses) included as a regulatory liability/asset 0.6 21.7 1.7 (0.4 ) 3.4 Settlements (13.3 ) (32.1 ) (4.4 ) (1.9 ) (6.9 ) Balance as of June 30, $14.0 $16.2 $5.6 $2.0 $8.0 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2015 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $0.7 $25.5 $3.4 $4.1 $12.3 Issuances of FTRs 7.0 48.2 5.4 7.3 11.4 Gains (losses) included as a regulatory liability/asset 36.1 (4.7 ) 3.3 1.3 (16.0 ) Settlements (34.7 ) (31.7 ) (7.2 ) (6.0 ) 0.2 Balance as of June 30, $9.1 $37.3 $4.9 $6.7 $7.9
Entergy Texas [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $12.8 Entergy Louisiana Natural gas swaps Prepayments and other $2.7 Entergy Mississippi FTRs Prepayments and other $14.0 Entergy Arkansas FTRs Prepayments and other $16.2 Entergy Louisiana FTRs Prepayments and other $5.6 Entergy Mississippi FTRs Prepayments and other $2.0 Entergy New Orleans FTRs Prepayments and other $8.0 Entergy Texas 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 $1.4 million posted by Entergy Texas as of June 30, 2016. No cash collateral was required to be posted as of June 30, 2016 and December 31, 2015, respectively.
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2016 and 2015 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2016 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($4.9) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.9) (a) Entergy Mississippi FTRs Purchased power expense $5.5 (b) Entergy Arkansas FTRs Purchased power expense $21.6 (b) Entergy Louisiana FTRs Purchased power expense $3.6 (b) Entergy Mississippi FTRs Purchased power expense $1.4 (b) Entergy New Orleans FTRs Purchased power expense $5.4 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $2.5 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.6 (a) Entergy Mississippi FTRs Purchased power expense $19.6 (b) Entergy Arkansas FTRs Purchased power expense $17.3 (b) Entergy Louisiana FTRs Purchased power expense $3.9 (b) Entergy Mississippi FTRs Purchased power expense $4.5 (b) Entergy New Orleans FTRs Purchased power expense $1.2 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 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 ($24.2) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($5.0) (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 $13.3 (b) Entergy Arkansas FTRs Purchased power expense $32.1 (b) Entergy Louisiana FTRs Purchased power expense $4.4 (b) Entergy Mississippi FTRs Purchased power expense $1.9 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 2015 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.5) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.4) (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 $34.7 (b) Entergy Arkansas FTRs Purchased power expense $31.7 (b) Entergy Louisiana FTRs Purchased power expense $7.2 (b) Entergy Mississippi FTRs Purchased power expense $6.0 (b) Entergy New Orleans FTRs Purchased power expense ($0.2) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of 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 $54.6 $— $— $54.6 Securitization recovery trust account 29.4 — — 29.4 FTRs — — 8.0 8.0 $84.0 $— $8.0 $92.0 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 June 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of April 1, $3.7 $3.3 $0.9 $0.6 $0.9 Issuances of FTRs 18.8 18.1 5.9 2.8 9.3 Gains (losses) included as a regulatory liability/asset (3.0 ) 16.4 2.4 — 3.2 Settlements (5.5 ) (21.6 ) (3.6 ) (1.4 ) (5.4 ) Balance as of June 30, $14.0 $16.2 $5.6 $2.0 $8.0 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2015 . Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $0.6 $8.8 $0.9 $1.4 $3.4 Issuances of FTRs 7.0 48.2 5.4 7.3 11.4 Gains (losses) included as a regulatory liability/asset 21.1 (2.4 ) 2.5 2.5 (5.7 ) Settlements (19.6 ) (17.3 ) (3.9 ) (4.5 ) (1.2 ) Balance as of June 30, $9.1 $37.3 $4.9 $6.7 $7.9 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 six months ended June 30, 2016 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $7.9 $8.5 $2.4 $1.5 $2.2 Issuances of FTRs 18.8 18.1 5.9 2.8 9.3 Gains (losses) included as a regulatory liability/asset 0.6 21.7 1.7 (0.4 ) 3.4 Settlements (13.3 ) (32.1 ) (4.4 ) (1.9 ) (6.9 ) Balance as of June 30, $14.0 $16.2 $5.6 $2.0 $8.0 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2015 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $0.7 $25.5 $3.4 $4.1 $12.3 Issuances of FTRs 7.0 48.2 5.4 7.3 11.4 Gains (losses) included as a regulatory liability/asset 36.1 (4.7 ) 3.3 1.3 (16.0 ) Settlements (34.7 ) (31.7 ) (7.2 ) (6.0 ) 0.2 Balance as of June 30, $9.1 $37.3 $4.9 $6.7 $7.9
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 $138.0 $— $— $138.0 Decommissioning trust funds (a): Equity securities 0.7 — — 0.7 Debt securities 247.4 56.3 — 303.7 Common trusts (b) 436.7 $386.1 $56.3 $— $879.1 2015 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $222.0 $— $— $222.0 Decommissioning trust funds (a): Equity securities 1.8 — — 1.8 Debt securities 218.6 59.2 — 277.8 Common trusts (b) 421.9 $442.4 $59.2 $— $923.5

Decommissioning Trust Funds (Ta

Decommissioning Trust Funds (Tables)	6 Months Ended
	Jun. 30, 2016
Securities Held	The securities held as of June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,283 $1,467 $1 Debt Securities 2,273 108 1 Total $5,556 $1,575 $2 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $24 $1 $84 $— More than 12 months 1 — 33 1 Total $25 $1 $117 $1 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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $73 $77 1 year - 5 years 839 857 5 years - 10 years 755 704 10 years - 15 years 152 124 15 years - 20 years 63 50 20 years+ 391 343 Total $2,273 $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 June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $497.6 $246.3 $0.1 Debt Securities 305.2 12.1 0.1 Total $802.8 $258.4 $0.2 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $4.5 $0.1 $18.2 $— More than 12 months — — 1.6 0.1 Total $4.5 $0.1 $19.8 $0.1 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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $5.4 $1.8 1 year - 5 years 119.9 145.2 5 years - 10 years 163.5 138.5 10 years - 15 years 9.7 2.4 15 years - 20 years 1.1 2.0 20 years+ 5.6 14.0 Total $305.2 $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 June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $658.6 $300.4 $— Debt Securities 436.2 24.7 0.3 Total $1,094.8 $325.1 $0.3 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1.6 $— $3.7 $— More than 12 months 0.8 — 6.8 0.3 Total $2.4 $— $10.5 $0.3 The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2015 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $18.9 $27.1 1 year - 5 years 115.0 124.0 5 years - 10 years 117.1 114.3 10 years - 15 years 51.8 39.3 15 years - 20 years 30.9 26.5 20 years+ 102.5 78.7 Total $436.2 $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 June 30, 2016 and December 31, 2015 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $437.4 $190.0 $0.1 Debt Securities 303.7 8.4 0.1 Total $741.1 $198.4 $0.2 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 June 30, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1.0 $0.1 $20.2 $— More than 12 months — — 1.1 0.1 Total $1.0 $0.1 $21.3 $0.1 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 June 30, 2016 and December 31, 2015 are as follows: 2016 2015 (In Millions) less than 1 year $3.1 $2.0 1 year - 5 years 192.2 181.2 5 years - 10 years 75.6 63.0 10 years - 15 years 3.6 4.4 15 years - 20 years 1.5 1.6 20 years+ 27.7 25.6 Total $303.7 $277.8

Commitments and Contingencies C

Commitments and Contingencies Commitments And Contingencies (Narrative) (Details) (Details)	1 Months Ended				6 Months Ended	12 Months Ended
	Jun. 30, 2016USD ($)MW	May 31, 2016USD ($)	Apr. 30, 2016USD ($)	Dec. 31, 2015USD ($)	Jun. 30, 2016USD ($)MW	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Regulatory Assets [Line Items]
Other Receivables	$ 237,480,000			$ 178,364,000	$ 237,480,000		$ 178,364,000
Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Other Receivables	7,436,000			8,276,000	7,436,000		8,276,000
Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Expected NRC inspection costs excluding remediation and response costs					30,600,000
Incremental NRC Inspection Costs							53,000,000
Other Receivables	82,046,000			84,216,000	82,046,000		84,216,000
Entergy Arkansas [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Expected NRC inspection costs excluding remediation and response costs						$ 50,000,000
Entergy Wholesale Commodities [Member] | Pilgrim [Member]
Regulatory Assets [Line Items]
Incremental NRC Inspection Costs					12,000,000
Entergy Wholesale Commodities [Member] | Minimum [Member] | Pilgrim [Member]
Regulatory Assets [Line Items]
Expected NRC inspection costs	45,000,000				45,000,000
Entergy Wholesale Commodities [Member] | Maximum [Member] | Pilgrim [Member]
Regulatory Assets [Line Items]
Expected NRC inspection costs	60,000,000				60,000,000
Entergy Wholesale Commodities [Member] | Subsequent Event [Member] | Pilgrim [Member]
Regulatory Assets [Line Items]
Expected NRC inspection costs						$ 30,000,000
Indian Point 3 and FitzPatrick [Domain]
Regulatory Assets [Line Items]
Litigation Settlement, Amount				81,000,000
Indian Point 3 [Domain]
Regulatory Assets [Line Items]
Damages awarded for previously capitalized costs				45,000,000
Damages awarded for previously recorded operation and maintenance				2,000,000
Reduction of previously recorded deprecation expense				8,000,000
Plant balance reduction				37,000,000
Fitzpatrick [Member]
Regulatory Assets [Line Items]
Damages awarded for previously capitalized costs				32,000,000
Damages awarded for previously recorded operation and maintenance				2,000,000
Plant balance reduction				11,000,000
Carrying Value of Nuclear Plant				0			0
Reduction to operation and maintenance expense				21,000,000
Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Litigation Settlement, Amount			$ 42,000,000
Damages awarded for previously capitalized costs	17,000,000
Damages awarded for previously recorded operation and maintenance	2,000,000
Reduction of previously recorded deprecation expense	3,000,000
Plant balance reduction	14,000,000
Receivable Related to Litigation Settlement	42,000,000				42,000,000
Other Receivables	112,044,000			$ 56,793,000	$ 112,044,000		$ 56,793,000
Previously recorded nuclear fuel expense	$ 23,000,000
Vermont Yankee [Member]
Regulatory Assets [Line Items]
Litigation Settlement, Amount		$ 19,000,000
Damages awarded for previously capitalized costs		15,000,000
Damages awarded for previously recorded operation and maintenance		4,000,000
Reduction of previously recorded deprecation expense		2,000,000
Reduction to operation and maintenance expense		$ 13,000,000
Pilgrim [Member]
Regulatory Assets [Line Items]
Capacity Supply Obligations in ISO New England | MW	677				677

Rate And Regulatory Matters (Na

Rate And Regulatory Matters (Narrative) (Details)	1 Months Ended													6 Months Ended		36 Months Ended
	Jul. 31, 2016USD ($)	Jun. 30, 2016USD ($)	May 31, 2016USD ($)	Apr. 30, 2016USD ($)	Mar. 31, 2016USD ($)	Feb. 29, 2016USD ($)	Jan. 31, 2016	Dec. 31, 2015USD ($)	Nov. 30, 2015USD ($)	Sep. 30, 2015USD ($)	Jul. 31, 2015USD ($)	Apr. 30, 2015USD ($)	Jan. 31, 2013USD ($)intervenor	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2016USD ($)	May 31, 2015USD ($)	Jan. 31, 2015USD ($)
Commitments and Contingencies [Abstract]
Deferred Fuel Cost		$ 31,895,000						$ 0						$ 31,895,000
Payments to Acquire Property, Plant, and Equipment														(947,903,000)	$ 0
Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Refund to customers per LPSC Staff January 2013 audit report													$ 1,900,000
Realignment of the recovery from Entergy Louisiana's fuel adjustment clause to base rates per LPSC January 2013 audit report													$ 1,000,000
Number of Parties That Intervened in LPSC Proceeding | intervenor													2
Number of Intervenors | intervenor													1
Commitments and Contingencies [Abstract]
Public Utilities Earned Return On Common Equity			9.07%				10.22%
LPSC staff recommended fuel refund including interest					$ 8,600,000
Amount of LPSC Recommended Realignment of Fuel Costs to Base Rates					12,700,000
Payments to Acquire Property, Plant, and Equipment					(474,000,000)									(473,956,000)	0
Estimated costs at completion for Ninemile 6 project											$ 648,000,000
Decrease in estimated costs at completion for Ninemile 6 project											76,000,000
Adjustment to formula rate plan to increase Legacy Entergy Louisiana additional capacity mechanism			$ 14,200,000
Adjustment to formula rate plan to increase Legacy Entergy Gulf States Louisiana additional capacity mechanism			500,000
Adjustment to formula rate plan to increase Legacy Entergy Louisiana revenues due to effect of system agreement termination			10,000,000
Adjustment to formula rate plan to decrease Legacy Entergy Gulf States Louisiana revenues due to effect of system agreement termination			58,700,000
Adjustment to formula rate plan for increase in MISO cost recovery mechanism			11,000,000
Entergy Mississippi [Member]
Commitments and Contingencies [Abstract]
Public Utilities Earned Return On Common Equity		10.07%
Deferred Fuel Over-Recovery Balance																	$ 58,300,000
Under-Recovery Under Power Management Rider																	$ 12,300,000
Net Over-Recovery of Rider Revenues											46,000,000
Projected Over-Recovery Energy Cost Recovery Rider						$ 68,000,000			$ 48,000,000
Public Utilities, Requested Rate Increase (Decrease), Amount					$ 32,600,000
Public Utilities, Requested Return on Equity, Percentage					9.96%
Public Utilities, Approved Rate Increase (Decrease), Amount		$ 23,700,000
Rate Increase Included in Formula Rate Plan		19,400,000
Increase in expenses to be collected through ad valorem tax adjustment rider		4,300,000
Authorized Storm Damage Reserve Balance																		$ 15,000,000
Upper limit not exceeded for storm accrual balance				$ 10,000,000
Entergy New Orleans [Member]
Commitments and Contingencies [Abstract]
Long-term payable due to Entergy Louisiana		20,527,000						20,527,000						20,527,000
Payments to Acquire Property, Plant, and Equipment					$ (237,000,000)									(236,978,000)	0
Authorized monthly customer credits									400,000
Entergy New Orleans [Member] | Subsequent Event [Member]
Commitments and Contingencies [Abstract]
Monthly customer credits	$ 1,400,000
Proposed annual customer credits	5,000,000
Redemption of Preferred Equity	21,000,000
Call Premium on Preferred Stock	819,000
Entergy Texas [Member]
Commitments and Contingencies [Abstract]
Public Utilities, Requested Rate Increase (Decrease), Amount										$ 13,000,000
Refund To Customers		68,000,000		56,200,000
Refund for fuel cost recovery				41,800,000
System Agreement Bandwidth Refund Related to Calendar Year 2006 Production Costs											$ 10,900,000
System Agreement Bandwidth Refund Related to Calendar Year 2006-2008 Production Costs				$ 3,500,000
Reduction in approved retail rate increase									2,000,000
Intervenor Recommended Disallowance Due to Load Growth Adjustment									$ 3,400,000
Jurisdictional eligible fuel and purchased power expenses, net of credits																$ 1,770,000,000
Entergy Texas [Member] | Subsequent Event [Member]
Commitments and Contingencies [Abstract]
Public Utilities, Approved Rate Increase (Decrease), Amount	10,500,000
Estimated deferred fuel over recovery balance for reconciliation period	19,300,000
Entergy Arkansas [Member]
Commitments and Contingencies [Abstract]
APSC and Intervener Recommended Revenue Requirement										$ 217,900,000
APSC and Intervener Recommended Return on Equity										9.65%
Net increase in revenues								133,000,000				$ 167,000,000
Deferred Fuel Cost		$ 31,895,000						0						31,895,000
Public Utilities, Requested Rate Increase (Decrease), Amount												$ 268,400,000
Public Utilities, Requested Return on Equity, Percentage												10.20%
Public Utilities, Approved Rate Increase (Decrease), Amount								$ 225,000,000
Public Utilities, Approved Return on Equity, Percentage								9.75%
Basis Point Band								50.00%
Payments to Acquire Property, Plant, and Equipment					(237,000,000)									$ (236,969,000)	$ 0
Post-Fukushima Compliance Costs								$ 7,700,000
Flood Barrier Compliance Costs								$ 9,900,000
Reduction in approved retail rate increase						$ 5,000,000
Interim Base Rate Adjustment Surcharge Recovery					21,100,000
ALJ Recommended Percentage By Which Payments Be Reduced				20.00%
Liability Recorded Related to Estimated Payments Due Utility Operating Companies					87,000,000											87,000,000
Regulatory Asset Recorded to Represent Estimate of Recoverable Retail Portion of Costs					$ 75,000,000											$ 75,000,000
Redetermination Of Production Cost Allocation Rider Unrecovered Retail Balance			$ 1,900,000
Entergy Arkansas [Member] | Subsequent Event [Member]
Commitments and Contingencies [Abstract]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 68,000,000
Public Utilities, Requested Return on Equity, Percentage	9.75%

Equity (Narrative) (Details)

Equity (Narrative) (Details) - $ / shares	Jul. 29, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Equity [Abstract]
Stock Options Excluded From Diluted Common Shares Outstanding Calculation		4,100,000	5,100,000	5,100,000	4,300,000
Shares, Issued		507,144		507,144
Common stock dividend (in dollars per share)		$ 0.85	$ 0.83	$ 1.70	$ 1.66
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		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Basic earnings per share
Net income (loss) attributable to Entergy Corporation, Income	$ 567,314	$ 148,843	$ 797,280	$ 446,892
Net Income Attributable to Entergy Corporation, Shares	178,808,149	179,521,276	178,693,342	179,589,748
Net Income Attributable to Entergy Corporation, $/share	$ 3.17	$ 0.83	$ 4.46	$ 2.49
Average dilutive effect of:
Stock options, Shares	200,000	200,000	0	400,000
Stock options $/share	$ 0	$ 0	$ 0	$ (0.01)
Restricted stock, Shares	500,000	400,000	400,000	300,000
Restricted stock $/share	$ (0.01)	$ 0	$ (0.01)	$ 0
Diluted earnings per share, Shares	179,503,582	180,119,837	179,233,209	180,298,233
Diluted earnings per share $/share	$ 3.16	$ 0.83	$ 4.45	$ 2.48

Equity (Accumulated Other Compr

Equity (Accumulated Other Comprehensive Income (Loss))(Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	$ 29,792	$ (59,737)	$ 8,951	$ (42,307)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(11,026)	64,355	104,029	55,579
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(27,921)	(51,434)	(122,135)	(60,088)
Other comprehensive income (loss)	(38,947)	12,921	(18,106)	(4,509)
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	(9,155)	(46,816)	(9,155)	(46,816)
Foreign Currency Translation [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	1,744	2,118	2,028	2,669
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(904)	667	(1,188)	116
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	0	0	0	0
Other comprehensive income (loss)	(904)	667	(1,188)	116
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	840	2,785	840	2,785
Net Unrealized Investment Gains [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	390,626	430,698	367,557	426,695
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	24,016	(25,108)	49,048	(12,450)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(3,061)	(8,772)	(5,024)	(17,427)
Other comprehensive income (loss)	20,955	(33,880)	44,024	(29,877)
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	411,581	396,818	411,581	396,818
Pension And Other Postretirement Liabilities [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	(459,042)	(561,341)	(466,604)	(569,789)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0	0	0	13
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	5,043	7,438	12,605	15,873
Other comprehensive income (loss)	5,043	7,438	12,605	15,886
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	(453,999)	(553,903)	(453,999)	(553,903)
Cash Flow Hedges Net Unrealized Gain [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	96,464	68,788	105,970	98,118
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(34,138)	88,796	56,169	67,900
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(29,903)	(50,100)	(129,716)	(58,534)
Other comprehensive income (loss)	(64,041)	38,696	(73,547)	9,366
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	32,423	107,484	32,423	107,484
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)	(230)	412	(493)	792
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	(56,905)		(56,905)
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	(56,675)	(78,843)	(56,412)	(79,223)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(230)	412	(493)	792
Other comprehensive income (loss)	(230)	412	(493)	792
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	$ (56,905)	$ (78,431)	$ (56,905)	$ (78,431)

Equity (Reclassification out of

Equity (Reclassification out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016		Jun. 30, 2015
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Competitive Energy Revenue	$ 344,110	$ 439,306	$ 866,189		$ 1,081,896
Other Nonoperating Income (Expense)	(8,377)	(15,743)	(18,963)		(24,764)
INCOME BEFORE INCOME TAXES	323,617	253,503	698,805		706,903
Income taxes (benefits)	248,973	(99,781)	109,027		(250,252)
Consolidated net income	572,590	153,722	807,832	[1]	456,651	[1]
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Consolidated net income	27,921	51,434	122,135		60,088
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	3,061	8,772	5,024		17,427
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	45,975	77,587	199,933		91,109
Other Nonoperating Income (Expense)	30	(510)	(370)		(1,056)
INCOME BEFORE INCOME TAXES	46,005	77,077	199,563		90,053
Income taxes (benefits)	(16,102)	(26,977)	(69,847)		(31,519)
Consolidated net income	29,903	50,100	129,716		58,534
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)	6,000	17,201	9,850		34,171
Income taxes (benefits)	(2,939)	(8,429)	(4,826)		(16,744)
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	5,985	14,710		11,971
Amortization of loss	(15,177)	(17,588)	(30,352)		(35,176)
INCOME BEFORE INCOME TAXES	(7,822)	(11,603)	(15,642)		(23,205)
Income taxes (benefits)	2,779	4,165	3,037		7,332
Consolidated net income	(5,043)	(7,438)	(12,605)		(15,873)
Entergy Louisiana [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Nonoperating Income (Expense)	(1,870)	(4,588)	(5,615)		(4,788)
INCOME BEFORE INCOME TAXES	168,235	162,846	329,583		331,757
Income taxes (benefits)	85,090	(53,865)	35,348		(96,667)
Consolidated net income	253,325	108,981	364,931		235,090
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior-service credit	1,947	1,866	3,894		3,733
Amortization of loss	(1,573)	(2,535)	(3,142)		(5,070)
INCOME BEFORE INCOME TAXES	374	(669)	752		(1,337)
Income taxes (benefits)	(144)	257	(259)		545
Consolidated net income	$ 230	$ (412)	$ 493		$ (792)
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $10.6 million and $6.4 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						6 Months Ended
		Jul. 31, 2016	Jun. 30, 2016	May 31, 2016	Apr. 30, 2016	Mar. 31, 2016	Jan. 31, 2016	Jun. 30, 2016
Debt Instrument [Line Items]
Amount of Facility			$ 3,500,000					$ 3,500,000
Issuance of letters of credit, percentage of total borrowing capacity			50.00%					50.00%
Letters of Credit Outstanding, Amount			$ 1,000					$ 1,000
Line of credit facility, commitment fee percentage								0.275%
Amount Drawn/ Outstanding			240,000					$ 240,000
Commercial Paper program limit			1,500,000					1,500,000
Commercial Paper Amount Outstanding			$ 853,000					$ 853,000
Commercial Paper Program [Member]
Debt Instrument [Line Items]
Debt, weighted average interest rate			1.13%					1.13%
Credit Facility [Member]
Debt Instrument [Line Items]
Debt, weighted average interest rate			2.28%					2.28%
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] | Mortgage Bonds Five Point Sixty Six Percent Series due February Two Thousand Twenty Five [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage							5.66%
Redemption of debt instrument							$ 175,000
Entergy Arkansas [Member] | Three Point Five Percent Series First Mortgage Bonds Due April Two Thousand Twenty Six [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			3.50%				3.50%	3.50%
Issuance Of Debt			$ 55,000				$ 325,000
Entergy Louisiana [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings			$ 450,000					$ 450,000
Issuance of letters of credit, percentage of total borrowing capacity			50.00%					50.00%
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%
Issuance Of Debt						$ 200,000
Entergy Louisiana [Member] | Mortgage Bonds, Three Point Two Five Percent Series, Due April Twenty Twenty Eight [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage						3.25%
Issuance Of Debt						$ 425,000
Entergy Louisiana [Member] | Mortgage Notes, Waterford 3 Series [Member]
Debt Instrument [Line Items]
Issuance Of Debt						$ 51,972
Entergy Louisiana [Member] | Mortgage Bonds Three Point Zero Five Percent Series Due June Two Thousand Thirty One [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				3.05%
Issuance Of Debt				$ 325,000
Entergy Louisiana [Member] | Mortgage Bonds Six Point Two Percent Series Due July Two Thousand Thirty Three [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				6.20%
Redemption of debt instrument				$ 240,000
Entergy Louisiana [Member] | Mortgage Bonds Six Point One Eight Percent Series Due March Two Thousand Thirty Five [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				6.18%
Redemption of debt instrument				$ 85,000
Entergy Louisiana [Member] | Governmental Bonds, Three Point Three Seven Five Percent, Due September Twenty Twenty Eight [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage						3.375%
Issuance Of Debt						$ 83,680
Entergy Louisiana [Member] | Governmental Bonds, Three Point Five Zero Percent, Due June Twenty Thirty [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage						3.50%
Issuance Of Debt						$ 115,000
Entergy Louisiana [Member] | Pollution Control Revenue Bonds [Member]
Debt Instrument [Line Items]
Redemption of debt instrument					$ 198,680
Entergy Mississippi [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings			$ 175,000					$ 175,000
Consolidated debt ratio			65.00%					65.00%
Entergy Mississippi [Member] | Mortgage Bonds Two Point Eight Five Percent Series Due June Two Thousand Twenty Eight [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				2.85%
Issuance Of Debt				$ 375,000
Entergy Mississippi [Member] | Mortgage Bonds Three Point Two Five Percent Series Due June Two Thousand Sixteen [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			3.25%					3.25%
Redemption of debt instrument			$ 125,000
Entergy Mississippi [Member] | Mortgage Bonds Six Point Zero Percent Series Due November Two Thousand Thirty Two [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			6.00%					6.00%
Redemption of debt instrument			$ 75,000
Entergy Mississippi [Member] | Mortgage Bonds Six Point Two Five Percent Series Due April Two Thousand Thirty Four [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			6.25%					6.25%
Redemption of debt instrument			$ 100,000
Entergy Mississippi [Member] | Governmental Bonds Four Point Nine Zero Percent Series Due Two Thousand Twenty Two Independence County [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			4.90%					4.90%
Redemption of debt instrument			$ 30,000
Entergy Texas [Member]
Debt Instrument [Line Items]
Letters of credit posted to cover derivative exposure			1,400					$ 1,400
Authorized Short Term Borrowings			$ 200,000					$ 200,000
Issuance of letters of credit, percentage of total borrowing capacity			50.00%					50.00%
Letters of Credit Outstanding, Amount			$ 1,400					$ 1,400
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%
Issuance Of Debt						$ 125,000
System Energy [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings			$ 200,000					$ 200,000
System Energy [Member] | Five Point Eight Seven Five Percent Governmental Bonds Due 2022 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				5.875%
Redemption of debt instrument				$ 22,000
Long-term Debt, Gross				$ 156,000
Entergy Nuclear Vermont Yankee [Member]
Debt Instrument [Line Items]
Amount of Facility						$ 100,000
Line of credit facility, commitment fee percentage								0.25%
Amount Drawn/ Outstanding			59,000					$ 59,000
Line of Credit Facility, Interest Rate During Period								2.21%
Uncommitted Credit Facility			85,000					$ 85,000
Uncommitted Line of Credit Facility Interest Rate During Period								2.21%
Entergy New Orleans [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings			100,000					$ 100,000
Issuance of letters of credit, limit of total borrowing capacity			$ 10,000					$ 10,000
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%
Issuance Of Debt						$ 110,000
Entergy New Orleans [Member] | Mortgage Bonds Four Percent Series Due June Two Thousand Twenty Six [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				4.00%
Issuance Of Debt				$ 85,000
Entergy New Orleans [Member] | Mortgage Bonds Five Point Six Percent Series Due September Two Thousand Twenty Four [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			5.60%					5.60%
Redemption of debt instrument			$ 33,271
Entergy New Orleans [Member] | Mortgage Bonds Five Point Six Five Percent Series Due September Two Thousand Twenty Nine [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			5.65%					5.65%
Redemption of debt instrument			$ 37,772
System Energy VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding			$ 99,600					$ 99,600
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			$ 12,600					$ 12,600
Line of credit facility commitment fee as a percentage of undrawn commitment amount								0.10%
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%
Redemption of debt instrument						$ 20,000
Entergy Louisiana Waterford VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding			$ 59,500					$ 59,500
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								0.075%
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]							1.71%
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]							1.96%
Subsequent Event [Member] | Entergy Arkansas [Member] | Mortgage Bonds Six Point Three Eight Percent Series Due November Twenty Thirty Four [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		6.38%
Redemption of debt instrument		$ 60,000
Subsequent Event [Member] | Entergy Arkansas VIE [Member] | Variable Interest Entity Notes Payable Three Point Two Three Percent Series J Due July Two Thousand Sixteen [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		3.23%
Redemption of debt instrument		$ 55,000
[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 June 30, 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	Jun. 30, 2016USD ($)
Summary of the borrowings outstanding and capacity available under the facility
Capacity	$ 3,500
Amount Drawn/ Outstanding	240
Letters of Credit	6
Capacity Available	$ 3,254

Revolving Credit Facilities, 38

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Credit Facilities) (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2016USD ($)
Amount of Facility	$ 3,500,000
Amount Drawn/ Outstanding	240,000
Letters of Credit Outstanding, Amount	$ 1,000
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	1.71%	[2]
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Arkansas [Member] | Credit Facility Of Twenty Million [Member]
Expiration Date	Apr. 30, 2017
Amount of Facility	$ 20,000	[3]
Interest Rate	1.71%	[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	1.71%	[2]
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 6,400
Entergy Mississippi [Member] | Credit Facility Of Thirty Seven Point Five Million [Member]
Expiration Date	May 31, 2017
Amount of Facility	$ 37,500	[5]
Interest Rate	1.96%	[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, 2017
Amount of Facility	$ 35,000	[5]
Interest Rate	1.96%	[2]
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Twenty Million [Member]
Expiration Date	May 31, 2017
Amount of Facility	$ 20,000	[5]
Interest Rate	1.96%	[2]
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Ten Million [Member]
Expiration Date	May 31, 2017
Amount of Facility	$ 10,000	[5]
Interest Rate	1.96%	[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. 20, 2018
Amount of Facility	$ 25,000
Interest Rate	2.21%	[2]
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Texas [Member]
Letters of Credit Outstanding, Amount	$ 1,400
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	1.96%	[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 June 30, 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.
[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.
[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	Jun. 30, 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	6 Months Ended
	Jun. 30, 2016USD ($)
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount Drawn/ Outstanding	$ 240
Entergy Arkansas VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	May 16, 2019
Amount of Facility	$ 80
Weighted Average Interest Rate on Borrowings	2.075%
Amount Drawn/ Outstanding	$ 12.6
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
System Energy VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	May 16, 2019
Amount of Facility	$ 120
Weighted Average Interest Rate on Borrowings	2.075%
Amount Drawn/ Outstanding	$ 99.6
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	May 16, 2019
Amount of Facility	$ 105
Amount Drawn/ Outstanding	$ 0
Entergy Louisiana Waterford VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	May 16, 2019
Amount of Facility	$ 85
Weighted Average Interest Rate on Borrowings	1.95%
Amount Drawn/ Outstanding	$ 59.5

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	6 Months Ended
	Jun. 30, 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	Jun. 30, 2016		Dec. 31, 2015
Short-term Debt [Line Items]
Long-term Debt, Fair Value	$ 14,556,026	[1],[2]	$ 13,578,511	[3],[4]
Long-term Debt, Book Value	13,783,804		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	2,835,020	[1],[2]	2,498,108	[3],[4]
Long-term Debt, Book Value	2,830,658		2,629,839
Long term DOE obligations	182,000		181,000
Entergy Louisiana [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	5,859,090	[1],[2]	5,018,786	[3],[4]
Long-term Debt, Book Value	5,410,218		4,836,162
Capital Lease Obligations	57,000		109,000
Entergy Mississippi [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	1,153,791	[1],[2]	1,087,326	[3],[4]
Long-term Debt, Book Value	1,091,938		1,045,085
Entergy New Orleans [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	466,368	[1],[2]	351,040	[3],[4]
Long-term Debt, Book Value	459,095		342,880
Entergy Texas [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	1,704,985	[1],[2]	1,590,616	[3],[4]
Long-term Debt, Book Value	1,539,889		1,451,967
System Energy [Member]
Short-term Debt [Line Items]
Long-term Debt, Fair Value	543,935	[1],[2]	552,762	[3],[4]
Long-term Debt, Book Value	550,926		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 $57 million at Entergy Louisiana and $34 million at System Energy, long-term DOE obligations of $182 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	Jun. 30, 2016USD ($)
Letters of Credit Outstanding, Amount	$ 1
Entergy Texas [Member]
Letters of Credit Outstanding, Amount	1.4
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	$ 14.4
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	$ 26.7
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	$ 13.3
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	$ 59.1

Stock Based Compensation (Narra

Stock Based Compensation (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	Jan. 28, 2016	Jan. 31, 2016	Mar. 31, 2016	Jun. 30, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option granted (in shares)			696,900
Weighted-average grant-date fair value of options granted (in dollars per share)			$ 7.40
Stock options outstanding				7,386,878
Weighted-average exercise price of stock options outstanding (in dollars per share)				$ 84.48
Intrinsic value in the money stock options				$ 36.2
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		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 1.1	$ 1	$ 2.2	$ 2.1
Tax benefit recognized in Entergy's net income	0.4	0.4	0.8	0.8
Compensation cost capitalized as part of fixed assets and inventory	$ 0.2	$ 0.2	$ 0.4	$ 0.4

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		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 8.5	$ 8	$ 16.9	$ 16.1
Tax benefit recognized in Entergy's net income	3.3	3.1	6.5	6.2
Compensation cost capitalized as part of fixed assets and inventory	$ 1.9	$ 1.6	$ 3.7	$ 3.1

Retirement And Other Postreti47

Retirement And Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2016
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Expected current year pension contributions			$ 169,800
Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
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			36,549
Remaining estimated pension contributions to be made in current year	$ 46,282		46,282
Entergy Arkansas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Pension contributions made through Year To Date					82,831
Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Expected current year pension contributions			6,999
Remaining estimated pension contributions to be made in current year	8,771		8,771
Entergy Texas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Pension contributions made through Year To Date					$ 15,770
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	8,500	$ 8,900
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	212	226
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	$ 254	$ 298

Retirement And Other Postreti48

Retirement And Other Postretirement Benefits (Components Of Qualified Net Pension Cost) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	$ 35,811	$ 43,762	$ 71,622	$ 87,524
Interest cost on projected benefit obligation	65,403	75,694	130,806	151,388
Expected return on assets	(97,366)	(98,655)	(194,732)	(197,310)
Amortization of prior service cost (credit)	270	390	540	780
Amortization of loss	48,824	58,981	97,648	117,962
Defined Benefit Plan, Special Termination Benefits			0	76
Net other postretirement benefit cost	52,942	80,172	105,884	160,420
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	10,362	13,322
Interest cost on projected benefit obligation	13,055	15,471	26,110	30,942
Expected return on assets	(19,772)	(20,026)	(39,544)	(40,052)
Amortization of loss	10,936	13,564	21,872	27,128
Net other postretirement benefit cost	9,400	15,670	18,800	31,340
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	14,098	17,198
Interest cost on projected benefit obligation	14,870	17,367	29,740	34,734
Expected return on assets	(22,096)	(22,701)	(44,192)	(45,402)
Amortization of loss	11,946	14,951	23,892	29,902
Net other postretirement benefit cost	11,769	18,216	23,538	36,432
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	3,124	3,964
Interest cost on projected benefit obligation	3,811	4,502	7,622	9,004
Expected return on assets	(5,981)	(6,105)	(11,962)	(12,210)
Amortization of loss	2,985	3,724	5,970	7,448
Net other postretirement benefit cost	2,377	4,103	4,754	8,206
Pension Plans Defined Benefit [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	656	849	1,312	1,698
Interest cost on projected benefit obligation	1,814	2,108	3,628	4,216
Expected return on assets	(2,687)	(2,725)	(5,374)	(5,450)
Amortization of loss	1,615	2,013	3,230	4,026
Net other postretirement benefit cost	1,398	2,245	2,796	4,490
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	2,832	3,290
Interest cost on projected benefit obligation	3,557	4,354	7,114	8,708
Expected return on assets	(6,062)	(6,222)	(12,124)	(12,444)
Amortization of loss	2,340	3,238	4,680	6,476
Net other postretirement benefit cost	1,251	3,015	2,502	6,030
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	3,132	3,914
Interest cost on projected benefit obligation	2,992	3,493	5,984	6,986
Expected return on assets	(4,459)	(4,568)	(8,918)	(9,136)
Amortization of loss	2,604	3,264	5,208	6,528
Net other postretirement benefit cost	2,703	4,146	5,406	8,292
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	8,073	11,326	16,146	22,652
Interest cost on projected benefit obligation	14,083	17,984	28,166	35,968
Expected return on assets	(10,455)	(11,344)	(20,910)	(22,688)
Amortization of prior service cost (credit)	(11,373)	(9,320)	(22,746)	(18,640)
Amortization of loss	4,554	7,893	9,108	15,786
Net other postretirement benefit cost	4,882	16,539	9,764	33,078
Other Postretirement [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	978	1,739	1,956	3,478
Interest cost on projected benefit obligation	2,324	3,130	4,648	6,260
Expected return on assets	(4,464)	(4,798)	(8,928)	(9,596)
Amortization of prior service cost (credit)	(1,368)	(610)	(2,736)	(1,220)
Amortization of loss	1,064	1,339	2,128	2,678
Net other postretirement benefit cost	(1,466)	800	(2,932)	1,600
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,869	2,474	3,738	4,948
Interest cost on projected benefit obligation	3,260	4,078	6,520	8,156
Expected return on assets	0	0	0	0
Amortization of prior service cost (credit)	(1,947)	(1,867)	(3,894)	(3,734)
Amortization of loss	732	1,780	1,464	3,560
Net other postretirement benefit cost	3,914	6,465	7,828	12,930
Other Postretirement [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	386	507	772	1,014
Interest cost on projected benefit obligation	709	859	1,418	1,718
Expected return on assets	(1,379)	(1,542)	(2,758)	(3,084)
Amortization of prior service cost (credit)	(234)	(229)	(468)	(458)
Amortization of loss	223	215	446	430
Net other postretirement benefit cost	(295)	(190)	(590)	(380)
Other Postretirement [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	156	205	312	410
Interest cost on projected benefit obligation	448	652	896	1,304
Expected return on assets	(1,154)	(1,201)	(2,308)	(2,402)
Amortization of prior service cost (credit)	(186)	(177)	(372)	(354)
Amortization of loss	37	118	74	236
Net other postretirement benefit cost	(699)	(403)	(1,398)	(806)
Other Postretirement [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	398	500	796	1,000
Interest cost on projected benefit obligation	1,039	1,342	2,078	2,684
Expected return on assets	(2,394)	(2,588)	(4,788)	(5,176)
Amortization of prior service cost (credit)	(681)	(681)	(1,362)	(1,362)
Amortization of loss	537	685	1,074	1,370
Net other postretirement benefit cost	(1,101)	(742)	(2,202)	(1,484)
Other Postretirement [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	334	470	668	940
Interest cost on projected benefit obligation	529	628	1,058	1,256
Expected return on assets	(814)	(911)	(1,628)	(1,822)
Amortization of prior service cost (credit)	(393)	(366)	(786)	(732)
Amortization of loss	287	300	574	600
Net other postretirement benefit cost	(57)	121	(114)	242
Non-Qualified Pension Plans [Member] | Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	4,300	4,500	8,500	8,900
Non-Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	106	113	212	226
Non-Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	59	68	118	136
Non-Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	59	59	118	118
Non-Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	16	16	32	32
Non-Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	$ 127	$ 149	$ 254	$ 298

Retirement And Other Postreti49

Retirement And Other Postretirement Benefits (Expected Employer Contributions) (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2016	Dec. 31, 2016
Change in Plan Assets
Expected current year pension contributions	$ 169,800
Subsequent Event [Member]
Change in Plan Assets
Pension contributions made through Year To Date		$ 387,500
Entergy Arkansas [Member]
Change in Plan Assets
Expected current year pension contributions	36,549
Remaining estimated pension contributions to be made in current year	46,282
Entergy Arkansas [Member] | Subsequent Event [Member]
Change in Plan Assets
Pension contributions made through Year To Date		82,831
Entergy Louisiana [Member]
Change in Plan Assets
Expected current year pension contributions	37,319
Remaining estimated pension contributions to be made in current year	46,590
Entergy Louisiana [Member] | Subsequent Event [Member]
Change in Plan Assets
Pension contributions made through Year To Date		83,909
Entergy Mississippi [Member]
Change in Plan Assets
Expected current year pension contributions	8,919
Remaining estimated pension contributions to be made in current year	10,994
Entergy Mississippi [Member] | Subsequent Event [Member]
Change in Plan Assets
Pension contributions made through Year To Date		19,913
Entergy New Orleans [Member]
Change in Plan Assets
Expected current year pension contributions	4,680
Remaining estimated pension contributions to be made in current year	6,014
Entergy New Orleans [Member] | Subsequent Event [Member]
Change in Plan Assets
Pension contributions made through Year To Date		10,694
Entergy Texas [Member]
Change in Plan Assets
Expected current year pension contributions	6,999
Remaining estimated pension contributions to be made in current year	8,771
Entergy Texas [Member] | Subsequent Event [Member]
Change in Plan Assets
Pension contributions made through Year To Date		15,770
System Energy [Member]
Change in Plan Assets
Expected current year pension contributions	8,891
Remaining estimated pension contributions to be made in current year	$ 11,315
System Energy [Member] | Subsequent Event [Member]
Change in Plan Assets
Pension contributions made through Year To Date		$ 20,206

Retirement And Other Postreti50

Retirement And Other Postretirement Benefits (Reclassification Out Of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Defined Benefit Plan Disclosure [Line Items]
Total
Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	$ 7,355	5,985	$ 14,710	$ 11,971
Amortization of loss	(15,177)	(17,588)	(30,352)	(35,176)
Total	(7,822)	(11,603)	(15,642)	(23,205)
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,947	1,866	3,894	3,733
Amortization of loss	(1,573)	(2,535)	(3,142)	(5,070)
Total	374	(669)	752	(1,337)
Pension Plans Defined Benefit [Member] | Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(270)	(389)	(540)	(778)
Amortization of loss	(12,482)	(12,627)	(24,964)	(25,254)
Total	(12,752)	(13,016)	(25,504)	(26,032)
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0	0	0
Amortization of loss	(836)	(751)	(1,672)	(1,502)
Total	(836)	(751)	(1,672)	(1,502)
Other Postretirement [Member] | Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	7,738	6,482	15,476	12,964
Amortization of loss	(2,063)	(4,409)	(4,126)	(8,818)
Total	5,675	2,073	11,350	4,146
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,947	1,867	3,894	3,734
Amortization of loss	(732)	(1,779)	(1,464)	(3,558)
Total	1,215	88	2,430	176
Non-Qualified Pension Plans [Member] | Parent Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(113)	(108)	(226)	(215)
Amortization of loss	(632)	(552)	(1,262)	(1,104)
Total	(745)	(660)	(1,488)	(1,319)
Non-Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	(1)	0	(1)
Amortization of loss	(5)	(5)	(6)	(10)
Total	$ (5)	$ (6)	$ (6)	$ (11)

Business Segment Information (S

Business Segment Information (Segment Financial Information) (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016		Jun. 30, 2015		Dec. 31, 2015
Segment Financial Information
Operating revenues	$ 2,462,562,000	$ 2,713,231,000	$ 5,072,415,000		$ 5,633,321,000
Income taxes (benefits)	(248,973,000)	99,781,000	(109,027,000)		250,252,000
Consolidated net income	572,590,000	153,722,000	807,832,000	[1]	456,651,000	[1]
Assets	45,877,042,000		45,877,042,000				$ 44,647,681,000
Utility [Member]
Segment Financial Information
Operating revenues	2,118,478,000	2,273,945,000	4,206,272,000		4,551,455,000
Income taxes (benefits)	(3,785,000)	117,798,000	104,051,000		209,048,000
Consolidated net income	380,317,000	204,035,000	579,968,000		431,786,000
Assets	39,841,100,000		39,841,100,000				38,356,906,000
Entergy Wholesale Commodities [Member]
Segment Financial Information
Operating revenues	344,110,000	439,306,000	866,189,000		1,081,896,000
Income taxes (benefits)	(235,055,000)	(3,300,000)	(182,741,000)		66,891,000
Consolidated net income	250,874,000	(3,545,000)	330,430,000		119,887,000
Assets	7,913,442,000		7,913,442,000				8,210,183,000
All Other [Member]
Segment Financial Information
Operating revenues	0	0	0		0
Income taxes (benefits)	(10,133,000)	(14,717,000)	(30,337,000)		(25,687,000)
Consolidated net income	(26,703,000)	(14,870,000)	(38,769,000)		(31,224,000)
Assets	1,211,715,000		1,211,715,000				(461,505,000)
Eliminations [Member]
Segment Financial Information
Operating revenues	(26,000)	(20,000)	(46,000)		(30,000)
Income taxes (benefits)	0	0	0		0
Consolidated net income	(31,898,000)	$ (31,898,000)	(63,797,000)		$ (63,798,000)
Assets	$ (3,089,215,000)		$ (3,089,215,000)				$ (1,457,903,000)
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2016 and 2015 include $10.6 million and $6.4 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		6 Months Ended		12 Months Ended
	Jun. 30, 2016USD ($)MWhMMBTU	Jun. 30, 2015USD ($)	Jun. 30, 2016USD ($)MWhMMBTUcounterparty	Jun. 30, 2015USD ($)	Dec. 31, 2015USD ($)counterparty
Risk Management and Fair Values [Abstract]
Letters of Credit Held	$ 23		$ 23
Letters of Credit Outstanding, Amount	1		1
Cash collateral posted	1		1		$ 9
Derivative, Collateral, Obligation to Return Cash					$ 68
Cash flow hedges relating to power sales as part of net unrealized gains			53
Reclassified from accumulated other comprehensive income (OCI) to operating revenues			$ 51
Number of Derivative Contract Counterparties in a Liability Position | counterparty			4		2
Maturity of cash flow hedges, Tax	$ 16	$ 27	$ 70	$ 32
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			87.00%
Planned Generation Sold Forward under financial derivatives	60.00%		60.00%
Total planned generation for remainder of the period | MWh			18,000,000
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	32,588,000		32,588,000
Total volume of fixed transmission rights outstanding | MWh	103,995,000		103,995,000
Change in cash flow hedges due to ineffectiveness	$ (3)	2	$ 0	1
Dollar amount of hedge contract in a liability position	7		$ 7		$ 2
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset and Liability Unrealized Gains (Loss) Included in Earnings	$ (6)	$ (1)		$ (7)
Entergy Arkansas [Member]
Risk Management and Fair Values [Abstract]
Total volume of fixed transmission rights outstanding | MWh	23,627,000		23,627,000
Entergy Louisiana [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	26,370,000		26,370,000
Total volume of fixed transmission rights outstanding | MWh	44,556,000		44,556,000
Entergy Mississippi [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	5,950,000		5,950,000
Total volume of fixed transmission rights outstanding | MWh	16,903,000		16,903,000
Entergy New Orleans [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	268,000		268,000
Total volume of fixed transmission rights outstanding | MWh	5,064,000		5,064,000
Entergy Texas [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount	$ 1.4		$ 1.4
Total volume of fixed transmission rights outstanding | MWh	13,301,000		13,301,000

Risk Management and Fair Valu53

Risk Management and Fair Values (Fair Values Of Derivative Instruments) (Details) - USD ($) $ in Millions		Jun. 30, 2016	Dec. 31, 2015
Assets:
Derivative asset as hedging instrument offset			$ (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]	$ 7	2
Derivative liability as hedging instrument offset	[2]	(5)	(2)
Derivative Liability	[3],[4]	2	0
Other Non-Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	[1]	3
Derivative liability as hedging instrument offset	[2]	(1)
Derivative Liability	[3],[4]	2
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]	5	17
Derivative asset as hedging instrument offset	[2]	(5)	(2)
Derivative Asset	[3],[4]	0	15
Other Deferred Debits And Other Assets [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset	[1]	8
Derivative asset as hedging instrument offset	[2]	0
Derivative Asset	[3],[4]	8
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]	50	173
Derivative asset as hedging instrument offset	[2]	(9)	(34)
Derivative Asset	[3],[4]	41	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]	50	54
Derivative asset as hedging instrument offset	[2]	(22)	(13)
Derivative Asset	[3],[4]	28	41
Prepayments And Other [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset		16
Derivative Asset		16
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]	47	24
Derivative asset as hedging instrument offset	[2]	(1)	(1)
Derivative Asset	[3],[4]	46	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]	7	14
Derivative liability as hedging instrument offset	[2]	(7)	(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]	31	38
Derivative liability as hedging instrument offset	[2]	(24)	(32)
Derivative Liability	[3],[4]	7	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
Derivative liability as hedging instrument offset	[2]		0
Derivative Liability	[3],[4]		9
Entergy Louisiana [Member] | Prepayments And Other [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset		12.8
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		16.2	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
Entergy Mississippi [Member] | Prepayments And Other [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset		2.7
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		5.6	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			1.3
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		2	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		14	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		$ 8	$ 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 $1 million posted as of June 30, 2016 and $9 million posted and $68 million held as of December 31, 2015. Also excludes letters of credit in the amount of $1 million posted and $23 million held as of June 30, 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		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Effect of Derivative instruments designated as cash flow hedges on consolidated statements of income
Amount of gain (loss) recognized in AOCI (effective portion)	$ (53)	$ 137	$ 86	$ 105
Amount of gain reclassified from accumulated OCI into income (effective portion)	$ 46	$ 78	$ 200	$ 91

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		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Competitive Businesses Operating Revenues [Member] | Electricity Swaps And Options [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recognized in AOCI	$ (10)	$ (3)	$ 15	$ 1
Amount of gain (loss) recorded in income	(6)	(5)	(9)	(39)
Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recognized in AOCI	0	0	0	0
Amount of gain (loss) recorded in income	(6)	3	(30)	(16)
Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recognized in AOCI	0	0	0	0
Amount of gain (loss) recorded in income	38	46	59	79
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	5.5	19.6	13.3	34.7
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	(4.9)	2.5	(24.2)	(13.5)
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	21.6	17.3	32.1	31.7
Entergy Mississippi [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	(0.9)	0.6	(5)	(2.4)
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	3.6	3.9	4.4	7.2
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	1.4	4.5	1.9	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	$ 5.4	$ 1.2	$ 6.9	$ (0.2)

Risk Management and Fair Valu56

Risk Management and Fair Values (Assets And Liabilities At Fair Value On A Recurring Basis) (Details) - USD ($) $ in Millions		Jun. 30, 2016	Dec. 31, 2015
Assets at fair value on a recurring basis
Assets other than temporary cash investments		$ 5,556	$ 5,350
Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		893	1,287
Liabilities at fair value on a recurring basis
Total			15
Assets, Fair Value Disclosure		7,058	7,330
Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			9
Power Contracts Liabilities [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		11	6
Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	464	468
Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	2,273	2,155
Common trust funds valued using Net Asset Value [Domain] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1],[2]	2,819	2,727
Power Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		77	195
Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		433	425
Gas Hedge Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		16
Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		37	50
Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		46	23
Fair Value Inputs Level 1 [Member]
Assets at fair value on a recurring basis
Temporary cash investments		893	1,287
Liabilities at fair value on a recurring basis
Total			9
Assets, Fair Value Disclosure		2,896	3,291
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			9
Fair Value Inputs Level 1 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	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]	464	468
Fair Value Inputs Level 1 [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	1,053	1,061
Fair Value Inputs Level 1 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value Inputs Level 1 [Member] | Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		433	425
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		16
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		37	50
Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 2 [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Total			0
Assets, Fair Value Disclosure		1,220	1,094
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
Fair Value, Inputs, Level 2 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Fair Value, Inputs, Level 2 [Member] | 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]	1,220	1,094
Fair Value, Inputs, Level 2 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 2 [Member] | Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0
Fair Value, Inputs, Level 2 [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 3 [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Total			6
Assets, Fair Value Disclosure		123	218
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
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		11	6
Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 3 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		77	195
Fair Value, Inputs, Level 3 [Member] | Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		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		46	23
Entergy Louisiana [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		1,094.8	1,042.3
Entergy Louisiana [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		50.1	34.8
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,482.1	1,379.2
Entergy Louisiana [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			7
Entergy Louisiana [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	6.9	7.1
Entergy Louisiana [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	436.2	409.9
Entergy Louisiana [Member] | Common trust funds valued using Net Asset Value [Domain] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	651.7	625.3
Entergy Louisiana [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		305.2	290.4
Entergy Louisiana [Member] | Gas Hedge Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		12.8
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		3	3.2
Entergy Louisiana [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		16.2	8.5
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		50.1	34.8
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		515	496.6
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			7
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	6.9	7.1
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	137	161.1
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		305.2	290.4
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		12.8
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		3	3.2
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		299.2	248.8
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
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]	299.2	248.8
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		16.2	8.5
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
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] | Gas Hedge Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		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		16.2	8.5
Entergy Arkansas [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		802.8	771.3
Entergy Arkansas [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		11.3
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		838.4	795.6
Entergy Arkansas [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	16.8	3
Entergy Arkansas [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	305.2	303.9
Entergy Arkansas [Member] | Common trust funds valued using Net Asset Value [Domain] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	480.8	464.4
Entergy Arkansas [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		7.1	12.2
Entergy Arkansas [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		3.2	4.2
Entergy Arkansas [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		14	7.9
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		11.3
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		135.8	129.9
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	16.8	3
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	97.4	110.5
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		7.1	12.2
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		3.2	4.2
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		207.8	193.4
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	207.8	193.4
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		14	7.9
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[3]	0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		14	7.9
Entergy Mississippi [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		105.3	144.2
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		145.4	188.3
Entergy Mississippi [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			1.3
Entergy Mississippi [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		31.8	41.7
Entergy Mississippi [Member] | Gas Hedge Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		2.7
Entergy Mississippi [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		5.6	2.4
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		105.3	144.2
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		139.8	185.9
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			1.3
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		31.8	41.7
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		2.7
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
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] | Gas Hedge Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		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		5.6	2.4
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
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] | Gas Hedge Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		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		5.6	2.4
Entergy New Orleans [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		23.4	87.8
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		115	174.9
Entergy New Orleans [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0.5
Entergy New Orleans [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		88.3	81
Entergy New Orleans [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		1.3	4.6
Entergy New Orleans [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		2	1.5
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		23.4	87.8
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		113	173.4
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0.5
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		88.3	81
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		1.3	4.6
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		2	1.5
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		2	1.5
Entergy Texas [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		54.6
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		92	40.4
Entergy Texas [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		29.4	38.2
Entergy Texas [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		8	2.2
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		54.6
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		84	38.2
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		29.4	38.2
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
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		8	2.2
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		8	2.2
System Energy [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		741.1	701.5
System Energy [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		138	222
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		879.1	923.5
System Energy [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	0.7	1.8
System Energy [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	303.7	277.8
System Energy [Member] | Common trust funds valued using Net Asset Value [Domain] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	436.7	421.9
System Energy [Member] | Fair Value Inputs Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		138	222
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		386.1	442.4
System Energy [Member] | Fair Value Inputs Level 1 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	0.7	1.8
System Energy [Member] | Fair Value Inputs Level 1 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	247.4	218.6
System Energy [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		56.3	59.2
System Energy [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	0	0
System Energy [Member] | Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	56.3	59.2
System Energy [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0	0
System Energy [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	0	0
System Energy [Member] | Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	$ 0	$ 0
[1]	(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements herein for additional information on the investment portfolios.
[2]	(b)Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2016 and 2015: 2016 2015 Power Contracts FTRs Power Contracts FTRs (In Millions)Balance as of April 1,$183 $9 $145 $15Total gains (losses) for the period (a) Included in earnings(9) — 22 —Included in OCI(53) — 131 —Included as a regulatory liability/asset— 20 — 18Issuances of FTRs— 55 — 80Purchases— — 4 —Settlements(55) (38) (98) (46)Balance as of June 30,$66 $46 $204 $67
[3]	(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements herein for additional information on the investment portfolios.(b)Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

Risk Management and Fair 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		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Issuance of Fixed Transmission Rights	$ 0	$ 0	$ 0	$ 0
Electricity Swaps And Options [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	183	145	189	215
Total gains (losses) for the period (a)	(9)	22	(9)	(13)
Unrealized losses included in OCI	(53)	131	86	105
Included as a regulatory liability/asset	0	0	0	0
Purchases	0	4	0	14
Settlements	(55)	(98)	(200)	(117)
Balance as of June 30,	66	204	66	204
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	9	15	23	47
Total gains (losses) for the period (a)	0	0	0	(1)
Unrealized losses included in OCI	0	0	0	0
Included as a regulatory liability/asset	20	18	27	20
Issuance of Fixed Transmission Rights	55	80	55	80
Purchases	0	0	0	0
Settlements	(38)	(46)	(59)	(79)
Balance as of June 30,	46	67	46	67
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	3.7	0.6	7.9	0.7
Issuance of Fixed Transmission Rights	18.8	7	18.8	7
Unrealized gains included as a regulatory liability/asset	(3)	21.1	0.6	36.1
Settlements	(5.5)	(19.6)	(13.3)	(34.7)
Balance as of June 30,	14	9.1	14	9.1
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	3.3	8.8	8.5	25.5
Issuance of Fixed Transmission Rights	18.1	48.2	18.1	48.2
Unrealized gains included as a regulatory liability/asset	16.4	(2.4)	21.7	(4.7)
Settlements	(21.6)	(17.3)	(32.1)	(31.7)
Balance as of June 30,	16.2	37.3	16.2	37.3
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	0.9	0.9	2.4	3.4
Issuance of Fixed Transmission Rights	5.9	5.4	5.9	5.4
Unrealized gains included as a regulatory liability/asset	2.4	2.5	1.7	3.3
Settlements	(3.6)	(3.9)	(4.4)	(7.2)
Balance as of June 30,	5.6	4.9	5.6	4.9
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	0.6	1.4	1.5	4.1
Issuance of Fixed Transmission Rights	2.8	7.3	2.8	7.3
Unrealized gains included as a regulatory liability/asset	0	2.5	(0.4)	1.3
Settlements	(1.4)	(4.5)	(1.9)	(6)
Balance as of June 30,	2	6.7	2	6.7
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	0.9	3.4	2.2	12.3
Issuance of Fixed Transmission Rights	9.3	11.4	9.3	11.4
Unrealized gains included as a regulatory liability/asset	3.2	(5.7)	3.4	(16)
Settlements	(5.4)	(1.2)	(6.9)	0.2
Balance as of June 30,	$ 8	$ 7.9	$ 8	$ 7.9

Risk Management and Fair Valu58

Risk Management and Fair Values (Schedules Of Valuation Techniques) (Details) $ in Millions	Jun. 30, 2016USD ($)
Range From Average Percentage for Electricity Options	34.00%
Range from Average Percentage for Fair Value of Electricity Swaps	3.00%
Effect of Significant Unobservable Inputs on Fair Value of Electricity Swaps	$ 2
Effect of Significant Unobservable Inputs on Fair Value of Electricity Options	3
Fair Value of Electricity Options	5
Fair Value of Electricity Swaps	$ 61

Decommissioning Trust Funds (Na

Decommissioning Trust Funds (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts			$ 380		$ 342
Amortized cost of debt securities	$ 2,189		$ 2,189		2,124
Average coupon rate of debt securities	3.20%		3.20%
Average duration of debt securities, years			5 years 9 months 30 days
Average maturity of debt securities, years			9 years 2 months 21 days
Proceeds from the dispositions of debt securities	$ 504	$ 456	$ 1,233	$ 949
Gains from dispositions of debt securities, gross	10	19	20	45
Losses from dispositions of debt securities, gross	2	1	5	3
Entergy Arkansas [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 299.5		$ 299.5		301.8
Average coupon rate of debt securities	2.61%		2.61%
Average duration of debt securities, years			5 years 2 months 10 days
Average maturity of debt securities, years			5 years 11 months 9 days
Proceeds from the dispositions of debt securities	$ 45.2	64.9	$ 103.8	146.8
Gains from dispositions of debt securities, gross	0.4	0.3	1.2	5.4
Losses from dispositions of debt securities, gross	0.2	0	$ 0.3	0
Entergy Louisiana [Member]
Decommissioning Trust Funds [Abstract]
Percentage Interest in River Bend			30.00%
Amortized cost of debt securities	$ 413.4		$ 413.4		399.2
Average coupon rate of debt securities	3.85%		3.85%
Average duration of debt securities, years			5 years 5 months 21 days
Average maturity of debt securities, years			11 years 2 months 10 days
Proceeds from the dispositions of debt securities	$ 69.7	39.6	$ 123.5	65.2
Gains from dispositions of debt securities, gross	1.7	0.2	2.6	1.5
Losses from dispositions of debt securities, gross	0	0.2	0.1	0.2
System Energy [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 295.2		$ 295.2		$ 270.7
Average coupon rate of debt securities	1.87%		1.87%
Average duration of debt securities, years			5 years 2 months 13 days
Average maturity of debt securities, years			6 years 4 months 7 days
Proceeds from the dispositions of debt securities	$ 100.9	83.6	$ 289.4	162
Gains from dispositions of debt securities, gross	0.9	0.4	2.5	0.8
Losses from dispositions of debt securities, gross	$ 0.1	$ 0	$ 0.4	$ 0.1

Decommissioning Trust Funds (Se

Decommissioning Trust Funds (Securities Held) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Schedule of Available-for-sale Securities [Line Items]
Fair Value	$ 5,556	$ 5,350
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	1,575	1,437
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	2	19
Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	3,283	3,195
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	1,467	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	2,273	2,155
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	108	41
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	1	17
Entergy Arkansas [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	802.8	771.3
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	258.4	238.5
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.2	2.4
Entergy Arkansas [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	497.6	467.4
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	246.3	234.4
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.1	0.2
Entergy Arkansas [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	305.2	303.9
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	12.1	4.1
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.1	2.2
Entergy Louisiana [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	1,094.8	1,042.3
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	325.1	296.9
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.3	2.6
Entergy Louisiana [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	658.6	632.4
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	300.4	283.7
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0	0.2
Entergy Louisiana [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	436.2	409.9
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	24.7	13.2
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.3	2.4
System Energy [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	741.1	701.5
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	198.4	181.4
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.2	2.6
System Energy [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	437.4	423.7
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	190	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	303.7	277.8
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	8.4	2.2
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	$ 0.1	$ 2.3

Decommissioning Trust Funds (Av

Decommissioning Trust Funds (Available For Sale Securities Continuous Unrealized Loss Position Fair Value) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	$ 24	$ 54
More than 12 months Fair Value	1	1
Total Fair Value	25	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	84	1,031
More than 12 months Fair Value	33	61
Total Fair Value	117	1,092
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0	15
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	1	2
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	1	17
Entergy Arkansas [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	4.5	7.8
More than 12 months Fair Value	0	0
Total Fair Value	4.5	7.8
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 Arkansas [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	18.2	111.4
More than 12 months Fair Value	1.6	18.5
Total Fair Value	19.8	129.9
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0	1.7
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.1	0.5
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	0.1	2.2
Entergy Louisiana [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	1.6	9.4
More than 12 months Fair Value	0.8	0
Total Fair Value	2.4	9.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0	0.2
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0	0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	0	0.2
Entergy Louisiana [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	3.7	124
More than 12 months Fair Value	6.8	7.4
Total Fair Value	10.5	131.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0	2
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.3	0.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	0.3	2.4
System Energy [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	1	8.3
More than 12 months Fair Value	0	0.9
Total Fair Value	1	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	20.2	200.4
More than 12 months Fair Value	1.1	5
Total Fair Value	21.3	205.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0	2.2
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.1	0.1
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	$ 0.1	$ 2.3

Decommissioning Trust Funds (Fa

Decommissioning Trust Funds (Fair Value Of Debt Securities By Contractual Maturities) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Fair value of debt securities by contractual maturities
Less than 1 year	$ 73	$ 77
1 year - 5 years	839	857
5 years - 10 years	755	704
10 years - 15 years	152	124
15 years - 20 years	63	50
20 years+	391	343
Total	2,273	2,155
Entergy Arkansas [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	5.4	1.8
1 year - 5 years	119.9	145.2
5 years - 10 years	163.5	138.5
10 years - 15 years	9.7	2.4
15 years - 20 years	1.1	2
20 years+	5.6	14
Total	305.2	303.9
Entergy Louisiana [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	18.9	27.1
1 year - 5 years	115	124
5 years - 10 years	117.1	114.3
10 years - 15 years	51.8	39.3
15 years - 20 years	30.9	26.5
20 years+	102.5	78.7
Total	436.2	409.9
System Energy [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	3.1	2
1 year - 5 years	192.2	181.2
5 years - 10 years	75.6	63
10 years - 15 years	3.6	4.4
15 years - 20 years	1.5	1.6
20 years+	27.7	25.6
Total	$ 303.7	$ 277.8

Income Taxes Income Taxes (Narr

Income Taxes Income Taxes (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended
	Jun. 30, 2016	Jun. 30, 2016	Dec. 31, 2015
Regulatory Liability, Noncurrent	$ 1,485,402	$ 1,485,402	$ 1,414,898
Income tax benefit resulting from 2010-2011 IRS audit associated with Act 55 financing	63,500
Reduction in income tax expense related to permanent difference for nuclear decommissioning liability, net of unrecognized tax benefits		238,000
Entergy Arkansas [Member]
Regulatory Liability, Noncurrent	266,938	266,938	242,913
Entergy Louisiana [Member]
Regulatory Liability, Noncurrent	848,739	848,739	818,623
Unrecognized Tax Benefits	564,700	564,700	796,900
Income tax benefit resulting from 2010-2011 IRS audit associated with Act 55 financing	61,600
Income tax benefit resulting from 2010-2011 IRS audit related to Vidalia purchased power agreement	74,500
Regulatory liability for customer savings associated with Act 55 financing	16,100	16,100
Regulatory liability for customer savings associated with Act 55 financing, net of tax	9,900	9,900
Proceeds received from the LURC related to Act 55 financing of storm costs	148,600
System Energy [Member]
Regulatory Liability, Noncurrent	$ 353,331	$ 353,331	$ 337,424

Property, Plant, And Equipment

Property, Plant, And Equipment (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
	Mar. 31, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Construction expenditures in accounts payable		$ 138,000		$ 138,000		$ 234,000
Impairment of Long-Lived Assets Held-for-use				14,329	$ 0
Asset Write-Offs, Impairments, And Related Charges		6,969	$ 0	14,329	$ 0
Entergy Arkansas [Member]
Construction expenditures in accounts payable		20,400		20,400		43,000
Entergy Louisiana [Member]
Construction expenditures in accounts payable		43,300		43,300		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		2,300		2,300		11,400
Entergy New Orleans [Member]
Construction expenditures in accounts payable		200		200		1,500
Entergy Texas [Member]
Construction expenditures in accounts payable		11,500		11,500		33,100
System Energy [Member]
Construction expenditures in accounts payable		$ 11,800		$ 11,800		$ 6,800

Variable Interest Entities (Nar

Variable Interest Entities (Narrative) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 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	6 Months Ended
	Mar. 31, 2016USD ($)MW	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)
Payments to Acquire Property, Plant, and Equipment		$ (947,903)	$ 0
Union Power Station [Member]
Capacity Per Power Block | MW	495
Payments to Acquire Property, Plant, and Equipment	$ (949,000)
Capacity Of Power Plant Unit | MW	1,980
Entergy Arkansas [Member]
Payments to Acquire Property, Plant, and Equipment	$ (237,000)	(236,969)	0
Entergy Arkansas [Member] | Union Power Station [Member]
Percentage of Undivided Ownership Interest	25.00%
Payments to Acquire Property, Plant, and Equipment	$ (236,944)
Power Blocks Purchased	1
Entergy Louisiana [Member]
Payments to Acquire Property, Plant, and Equipment	$ (474,000)	(473,956)	0
Entergy Louisiana [Member] | Union Power Station [Member]
Percentage of Undivided Ownership Interest	50.00%
Payments to Acquire Property, Plant, and Equipment	$ (473,888)
Power Blocks Purchased	2
Entergy New Orleans [Member]
Payments to Acquire Property, Plant, and Equipment	$ (237,000)	$ (236,978)	$ 0
Entergy New Orleans [Member] | Union Power Station [Member]
Percentage of Undivided Ownership Interest	25.00%
Payments to Acquire Property, Plant, and Equipment	$ (236,944)
Power Blocks Purchased	1