System Energy Resources 10-Q 3 Aug 17 2017 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2017	Jul. 31, 2017
Entity Registrant Name	ENTERGY CORP /DE/
Entity Central Index Key	65,984
Document Type	10-Q
Document Period End Date	Jun. 30, 2017
Amendment Flag	false
Document Fiscal Year Focus	2,017
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		179,520,021
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, 2017	Jun. 30, 2016	Jun. 30, 2017		Jun. 30, 2016
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Tax	$ 10,684	$ (34,576)	$ 10,325		$ (39,777)
OPERATING REVENUES
Electric	2,271,220	2,093,331	4,262,960		4,135,492
Natural gas	30,075	25,121	73,426		70,734
Competitive businesses	317,255	344,110	870,622		866,189
TOTAL	2,618,550	2,462,562	5,207,008		5,072,415
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	395,947	381,465	813,513		886,432
Purchased power	416,497	242,672	774,264		504,996
Nuclear refueling outage expenses	38,288	47,045	80,853		98,276
Other operation and maintenance	820,297	759,258	1,687,845		1,491,174
Asset Write-Offs, Impairments, And Related Charges	193,571	6,969	405,362		14,329
Decommissioning	100,296	76,625	214,669		145,253
Taxes other than income taxes	153,264	149,249	309,616		299,027
Depreciation and amortization	350,328	335,668	697,593		669,939
Other regulatory charges (credits) - net	6,553	21,353	(78,749)		22,512
TOTAL	2,475,041	2,020,304	4,904,966		4,131,938
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property	0	0	(16,270)		0
OPERATING INCOME	143,509	442,258	318,312		940,477
OTHER INCOME
Allowance for equity funds used during construction	22,376	13,860	41,384		32,792
Investment Income, Net	80,097	46,375	136,646		79,128
Miscellaneous - net	(6,872)	(8,377)	(1,371)		(18,963)
TOTAL	95,601	51,858	176,659		92,957
INTEREST EXPENSE
Interest expense	173,377	177,631	344,466		351,442
Allowance for borrowed funds used during construction	(10,523)	(7,132)	(19,565)		(16,813)
TOTAL	162,854	170,499	324,901		334,629
INCOME BEFORE INCOME TAXES	76,256	323,617	170,070		698,805
Income taxes	(337,112)	(248,973)	(329,350)		(109,027)
CONSOLIDATED NET INCOME	413,368	572,590	499,420	[1]	807,832	[1]
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	3,446	5,276	6,892		10,552
EARNINGS APPLICABLE TO COMMON STOCK	$ 409,922	$ 567,314	$ 492,528		$ 797,280
Earnings per average common share:
Basic (in dollars per share)	$ 2.28	$ 3.17	$ 2.75		$ 4.46
Diluted (in dollars per share)	2.27	3.16	2.74		4.45
Dividends declared per common share (in dollars per share)	$ 0.87	$ 0.85	$ 1.74		$ 1.70
Basic average number of common shares outstanding (in shares)	179,475,346	178,808,149	179,405,592		178,693,342
Diluted average number of common shares outstanding (in shares)	180,234,694	179,503,582	180,032,233		179,233,209
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Tax	$ 5,839	$ 2,779	$ 12,216		$ 3,037
Other Comprehensive Income (Loss), Available-for-sale Securities, Tax	2,870	19,515	42,164		37,873
Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Tax	(403)	(487)	(403)		(640)
Entergy Arkansas [Member]
OPERATING REVENUES
Electric	496,662	504,252	971,013		969,625
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	50,691	88,022	150,100		168,959
Purchased power	74,552	49,714	129,685		111,518
Nuclear refueling outage expenses	17,335	14,981	36,954		30,050
Other operation and maintenance	171,821	173,909	337,678		326,815
Decommissioning	14,106	13,301	28,001		26,404
Taxes other than income taxes	25,128	22,961	49,179		46,047
Depreciation and amortization	69,087	67,115	136,153		130,288
Other regulatory charges (credits) - net	4,948	802	(5,578)		1,719
TOTAL	427,668	430,805	862,172		841,800
OPERATING INCOME	68,994	73,447	108,841		127,825
OTHER INCOME
Allowance for equity funds used during construction	5,432	3,995	9,782		8,927
Investment Income, Net	14,195	5,770	21,127		9,364
Miscellaneous - net	(57)	(1,020)	(164)		(1,795)
TOTAL	19,570	8,745	30,745		16,496
INTEREST EXPENSE
Interest expense	28,514	27,792	55,766		60,574
Allowance for borrowed funds used during construction	(2,552)	(2,136)	(4,514)		(4,851)
TOTAL	25,962	25,656	51,252		55,723
INCOME BEFORE INCOME TAXES	62,602	56,536	88,334		88,598
Income taxes	24,052	22,645	35,480		35,413
CONSOLIDATED NET INCOME	38,550	33,891	52,854		53,185
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	357	1,718	714		3,437
EARNINGS APPLICABLE TO COMMON STOCK	38,193	32,173	52,140		49,748
Entergy Louisiana [Member]
OPERATING REVENUES
Electric	1,072,126	989,732	1,936,202		1,926,163
Natural gas	11,308	9,302	28,015		28,016
TOTAL	1,083,434	999,034	1,964,217		1,954,179
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	180,056	152,340	334,100		354,423
Purchased power	282,673	224,699	522,500		416,097
Nuclear refueling outage expenses	12,764	12,974	24,949		25,754
Other operation and maintenance	243,217	232,957	466,447		439,021
Decommissioning	12,283	11,658	24,406		23,166
Taxes other than income taxes	45,076	44,366	90,359		86,728
Depreciation and amortization	116,107	112,452	231,737		222,043
Other regulatory charges (credits) - net	(2,521)	13,836	(76,708)		11,577
TOTAL	889,655	805,282	1,617,790		1,578,809
OPERATING INCOME	193,779	193,752	346,427		375,370
OTHER INCOME
Allowance for equity funds used during construction	11,109	4,506	21,099		11,744
Investment Income, Net	41,919	40,251	81,749		77,667
Miscellaneous - net	(2,650)	(1,870)	(5,674)		(5,615)
TOTAL	50,378	42,887	97,174		83,796
INTEREST EXPENSE
Interest expense	68,483	70,787	135,798		135,863
Allowance for borrowed funds used during construction	(5,541)	(2,383)	(10,715)		(6,280)
TOTAL	62,942	68,404	125,083		129,583
INCOME BEFORE INCOME TAXES	181,215	168,235	318,518		329,583
Income taxes	56,736	(85,090)	99,661		(35,348)
CONSOLIDATED NET INCOME	124,479	253,325	218,857		364,931
Earnings per average common share:
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Tax	(292)	(144)	(524)		(259)
Entergy Mississippi [Member]
OPERATING REVENUES
Electric	291,212	248,138	549,655		511,184
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	46,048	(34)	85,188		61,346
Purchased power	75,253	74,361	146,323		129,744
Other operation and maintenance	59,535	60,381	114,708		111,654
Taxes other than income taxes	23,978	20,487	47,950		43,984
Depreciation and amortization	35,442	34,010	70,759		67,308
Other regulatory charges (credits) - net	(4,306)	(2,957)	(10,143)		(6,315)
TOTAL	235,950	186,248	454,785		407,721
OPERATING INCOME	55,262	61,890	94,870		103,463
OTHER INCOME
Allowance for equity funds used during construction	2,332	1,345	4,175		2,631
Investment Income, Net	7	240	33		361
Miscellaneous - net	(553)	(1,050)	(978)		(1,755)
TOTAL	1,786	535	3,230		1,237
INTEREST EXPENSE
Interest expense	12,568	15,258	25,240		30,000
Allowance for borrowed funds used during construction	(913)	(691)	(1,633)		(1,358)
TOTAL	11,655	14,567	23,607		28,642
INCOME BEFORE INCOME TAXES	45,393	47,858	74,493		76,058
Income taxes	17,090	15,664	29,032		26,746
CONSOLIDATED NET INCOME	28,303	32,194	45,461		49,312
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	239	707	477		1,414
EARNINGS APPLICABLE TO COMMON STOCK	28,064	31,487	44,984		47,898
Entergy New Orleans [Member]
OPERATING REVENUES
Electric	157,455	149,101	299,800		271,542
Natural gas	18,767	15,819	45,411		42,718
TOTAL	176,222	164,920	345,211		314,260
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	22,961	12,554	53,036		23,475
Purchased power	73,105	70,583	141,464		139,108
Other operation and maintenance	25,296	28,659	47,808		51,501
Taxes other than income taxes	13,416	10,925	26,262		22,437
Depreciation and amortization	13,020	13,908	26,070		25,672
Other regulatory charges (credits) - net	818	1,378	1,203		3,274
TOTAL	148,616	138,007	295,843		265,467
OPERATING INCOME	27,606	26,913	49,368		48,793
OTHER INCOME
Allowance for equity funds used during construction	552	143	1,002		456
Investment Income, Net	164	30	299		99
Miscellaneous - net	40	192	138		(53)
TOTAL	756	365	1,439		502
INTEREST EXPENSE
Interest expense	5,356	5,984	10,699		10,357
Allowance for borrowed funds used during construction	(193)	(49)	(351)		(175)
TOTAL	5,163	5,935	10,348		10,182
INCOME BEFORE INCOME TAXES	23,199	21,343	40,459		39,113
Income taxes	8,317	9,500	14,599		16,103
CONSOLIDATED NET INCOME	14,882	11,843	25,860		23,010
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	241	241	482		482
EARNINGS APPLICABLE TO COMMON STOCK	14,641	11,602	25,378		22,528
Entergy Texas [Member]
OPERATING REVENUES
Electric	378,488	412,922	742,415		791,226
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	46,142	71,478	104,155		163,882
Purchased power	160,325	167,071	310,709		297,483
Other operation and maintenance	56,577	54,135	110,483		107,170
Taxes other than income taxes	19,251	18,285	38,695		36,595
Depreciation and amortization	29,373	26,495	57,484		52,114
Other regulatory charges (credits) - net	19,033	17,419	34,260		34,674
TOTAL	330,701	354,883	655,786		691,918
OPERATING INCOME	47,787	58,039	86,629		99,308
OTHER INCOME
Allowance for equity funds used during construction	1,632	2,270	2,913		4,702
Investment Income, Net	211	268	412		468
Miscellaneous - net	(631)	(54)	(813)		(470)
TOTAL	1,212	2,484	2,512		4,700
INTEREST EXPENSE
Interest expense	21,427	21,976	43,235		43,577
Allowance for borrowed funds used during construction	(1,001)	(1,473)	(1,762)		(3,054)
TOTAL	20,426	20,503	41,473		40,523
INCOME BEFORE INCOME TAXES	28,573	40,020	47,668		63,485
Income taxes	7,472	15,962	15,713		24,865
CONSOLIDATED NET INCOME	21,101	24,058	31,955		38,620
System Energy [Member]
OPERATING REVENUES
Electric	164,956	151,323	319,743		289,016
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	21,660	20,394	36,994		33,822
Nuclear refueling outage expenses	4,387	4,905	9,160		9,489
Other operation and maintenance	54,310	35,766	102,711		67,926
Decommissioning	13,452	12,593	26,684		24,980
Taxes other than income taxes	6,664	6,385	13,088		12,637
Depreciation and amortization	35,187	35,384	70,628		70,091
Other regulatory charges (credits) - net	(11,421)	(9,124)	(21,783)		(22,415)
TOTAL	124,239	106,303	237,482		196,530
OPERATING INCOME	40,717	45,020	82,261		92,486
OTHER INCOME
Allowance for equity funds used during construction	1,318	1,602	2,412		4,331
Investment Income, Net	3,723	5,124	8,397		8,398
Miscellaneous - net	(103)	(164)	(231)		(256)
TOTAL	4,938	6,562	10,578		12,473
INTEREST EXPENSE
Interest expense	9,181	9,382	18,300		18,934
Allowance for borrowed funds used during construction	(322)	(401)	(589)		(1,097)
TOTAL	8,859	8,981	17,711		17,837
INCOME BEFORE INCOME TAXES	36,796	42,601	75,128		87,122
Income taxes	17,446	17,511	35,431		36,074
CONSOLIDATED NET INCOME	$ 19,350	$ 25,090	$ 39,697		$ 51,048
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2017 and 2016 include $6.9 million and $10.6 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands		6 Months Ended
		Jun. 30, 2017	Jun. 30, 2016
OPERATING ACTIVITIES
Consolidated net income	[1]	$ 499,420	$ 807,832
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		1,042,671	1,012,753
Deferred income taxes, investment tax credits, and non-current taxes accrued		(324,227)	(170,026)
Impairment of Long-Lived Assets Held-for-use		220,828	14,329
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property		(16,270)	0
Changes in working capital:
Receivables		6,091	(57,673)
Fuel inventory		6,213	9,586
Accounts payable		9,687	45,412
Taxes accrued		(2,202)	7,056
Interest accrued		(3,947)	(9,543)
Deferred fuel costs		(127,945)	3,757
Other working capital accounts		(91,505)	(121,929)
Changes in provisions for estimated losses		(7,340)	1,533
Changes in other regulatory assets		62,612	109,700
Changes in other regulatory liabilities		(8,250)	70,505
Changes in pensions and other postretirement liabilities		(180,346)	(168,856)
Other Noncash Income (Expense)		(265,807)	(302,356)
Net cash flow provided by operating activities		819,683	1,252,080
INVESTING ACTIVITIES
Construction/capital expenditures		(1,719,712)	(1,294,498)
Allowance for equity funds used during construction		41,877	33,152
Payments to Acquire Property, Plant, and Equipment		0	(947,903)
Nuclear fuel purchases		(209,756)	(124,107)
Payments for Nuclear Fuel		(209,756)	(124,107)
Payments to storm reserve escrow account		(1,124)	(805)
Receipts from storm reserve escrow account		8,836	0
Decreases in other investments		1,705	57
Proceeds from Sale of Productive Assets		100,000	0
Proceeds from nuclear decommissioning trust fund sales		1,462,698	1,232,672
Investment in nuclear decommissioning trust funds		(1,516,406)	(1,267,452)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		25,493	89,407
Proceeds from insurance		26,157	0
Changes in securitization account		10,028	13,239
Net cash flow used in investing activities		(1,770,204)	(2,266,238)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		1,036,529	3,856,768
Common stock and treasury stock		7,819	16,855
Retirement of long-term debt		(866,337)	(3,420,196)
Changes in credit borrowings and commercial paper - net		833,957	530,540
Dividends paid:
Common stock		(312,209)	(303,843)
Preferred stock		(6,892)	(10,552)
Other		4,305	(10,276)
Net cash flow provided by financing activities		697,172	659,296
Net decrease in cash and cash equivalents		(253,349)	(354,862)
Cash and cash equivalents at beginning of period		1,187,844	1,350,961
Cash and cash equivalents at end of period		934,495	996,099
Cash paid / (received) during the period for:
Interest - net of amount capitalized		334,555	410,744
Income taxes		(14,673)	84,607
Entergy Arkansas [Member]
OPERATING ACTIVITIES
Consolidated net income		52,854	53,185
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		198,082	211,630
Deferred income taxes, investment tax credits, and non-current taxes accrued		38,005	122,195
Changes in working capital:
Receivables		12,092	(42,371)
Fuel inventory		(1,602)	5,093
Accounts payable		(29,109)	66,118
Taxes accrued		937	(89,124)
Interest accrued		1,816	(1,093)
Deferred fuel costs		(48,442)	(40,847)
Other working capital accounts		(32,055)	25,021
Changes in provisions for estimated losses		7,457	1,142
Changes in other regulatory assets		(5,592)	7,048
Changes in pensions and other postretirement liabilities		(40,637)	(45,752)
Other Noncash Income (Expense)		37,355	(18,542)
Net cash flow provided by operating activities		191,161	253,703
INVESTING ACTIVITIES
Construction/capital expenditures		(381,197)	(316,569)
Allowance for equity funds used during construction		10,198	9,229
Payments to Acquire Property, Plant, and Equipment		0	(236,969)
Change in money pool receivable - net		0	(1,453)
Nuclear fuel purchases		(92,927)	(64,689)
Payments for Nuclear Fuel		(92,927)	(64,689)
Proceeds from sale of nuclear fuel		51,029	40,336
Proceeds from nuclear decommissioning trust fund sales		167,329	103,815
Investment in nuclear decommissioning trust funds		(173,324)	(112,040)
Changes in securitization account		571	1,017
Other		0	(103)
Net cash flow used in investing activities		(418,321)	(577,426)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		222,937	380,141
Proceeds from Contributions from Parent		0	200,000
Retirement of long-term debt		(6,799)	(181,604)
Change in money pool payable - net		(37,563)	(52,742)
Changes in credit borrowings and commercial paper - net		31,436	908
Dividends paid:
Preferred stock		(714)	(3,437)
Other		431	(3,566)
Net cash flow provided by financing activities		209,728	339,700
Net decrease in cash and cash equivalents		(17,432)	15,977
Cash and cash equivalents at beginning of period		20,509	9,135
Cash and cash equivalents at end of period		3,077	25,112
Cash paid / (received) during the period for:
Interest - net of amount capitalized		51,232	58,733
Income taxes		0	7,242
Entergy Louisiana [Member]
OPERATING ACTIVITIES
Consolidated net income		218,857	364,931
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		300,805	301,815
Deferred income taxes, investment tax credits, and non-current taxes accrued		220,492	(49,661)
Changes in working capital:
Receivables		950	(72,931)
Fuel inventory		4,534	(5,053)
Accounts payable		42,079	(22,830)
Taxes accrued		52,686	23,850
Interest accrued		(2,883)	(4,216)
Deferred fuel costs		(74,113)	4,093
Other working capital accounts		(61,515)	(26,514)
Changes in provisions for estimated losses		(6,108)	1,734
Changes in other regulatory assets		39,711	58,429
Changes in other regulatory liabilities		(64,293)	30,116
Changes in pensions and other postretirement liabilities		(38,175)	(35,869)
Other Noncash Income (Expense)		(99,272)	(127,538)
Net cash flow provided by operating activities		533,755	440,356
INVESTING ACTIVITIES
Construction/capital expenditures		(755,158)	(403,387)
Allowance for equity funds used during construction		21,099	11,744
Payments to Acquire Property, Plant, and Equipment		0	(473,956)
Change in money pool receivable - net		(33,039)	(168)
Nuclear fuel purchases		(156,246)	(38,773)
Payments for Nuclear Fuel		(156,246)	(38,773)
Proceeds from sale of nuclear fuel		28,884	64,498
Payments to storm reserve escrow account		(802)	0
Receipts from storm reserve escrow account		8,836	0
Decreases in other investments		0	(544)
Proceeds from nuclear decommissioning trust fund sales		125,600	123,546
Investment in nuclear decommissioning trust funds		(144,768)	(143,091)
Proceeds from insurance		5,305	0
Changes in securitization account		79	225
Net cash flow used in investing activities		(900,210)	(859,906)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		532,219	1,128,580
Retirement of long-term debt		(101,789)	(559,839)
Changes in credit borrowings and commercial paper - net		30,696	(888)
Dividends paid:
Common stock		(91,250)	(105,500)
Other		(1,988)	(3,100)
Net cash flow provided by financing activities		367,888	459,253
Net decrease in cash and cash equivalents		1,433	39,703
Cash and cash equivalents at beginning of period		213,850	35,102
Cash and cash equivalents at end of period		215,283	74,805
Cash paid / (received) during the period for:
Interest - net of amount capitalized		134,513	196,514
Income taxes		(116,937)	62,676
Entergy Mississippi [Member]
OPERATING ACTIVITIES
Consolidated net income		45,461	49,312
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		70,759	67,308
Deferred income taxes, investment tax credits, and non-current taxes accrued		31,740	21,934
Changes in working capital:
Receivables		(7,952)	(24,273)
Fuel inventory		6,312	(5,040)
Accounts payable		(1,398)	21,359
Taxes accrued		(21,361)	(20,417)
Interest accrued		40	(584)
Deferred fuel costs		(13,622)	108
Other working capital accounts		(1,473)	(8,266)
Changes in provisions for estimated losses		(6,699)	(188)
Changes in other regulatory assets		(26,958)	(1,913)
Changes in pensions and other postretirement liabilities		(10,692)	(10,922)
Other Noncash Income (Expense)		(10,318)	(11,355)
Net cash flow provided by operating activities		53,839	77,063
INVESTING ACTIVITIES
Construction/capital expenditures		(199,873)	(143,171)
Allowance for equity funds used during construction		4,175	2,631
Change in money pool receivable - net		10,595	12,416
Other		(584)	(117)
Net cash flow used in investing activities		(185,687)	(128,241)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		0	371,940
Retirement of long-term debt		0	(332,400)
Change in money pool payable - net		56,299	0
Dividends paid:
Common stock		0	(24,000)
Preferred stock		(477)	(1,414)
Other		(86)	0
Net cash flow provided by financing activities		55,736	14,126
Net decrease in cash and cash equivalents		(76,112)	(37,052)
Cash and cash equivalents at beginning of period		76,834	145,605
Cash and cash equivalents at end of period		722	108,553
Cash paid / (received) during the period for:
Interest - net of amount capitalized		24,021	29,157
Income taxes		(15,087)	(3,561)
Entergy New Orleans [Member]
OPERATING ACTIVITIES
Consolidated net income		25,860	23,010
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		26,070	25,672
Deferred income taxes, investment tax credits, and non-current taxes accrued		14,764	(2,665)
Changes in working capital:
Receivables		(5,979)	(16,285)
Fuel inventory		(465)	1,822
Accounts payable		(8,761)	6,362
Taxes accrued		38	36,982
Interest accrued		(469)	255
Deferred fuel costs		2,087	(13,664)
Other working capital accounts		(11,774)	(7,310)
Changes in provisions for estimated losses		(1,794)	1,804
Changes in other regulatory assets		2,719	5,799
Changes in pensions and other postretirement liabilities		(8,049)	(8,245)
Other Noncash Income (Expense)		2,503	(14,269)
Net cash flow provided by operating activities		36,750	39,268
INVESTING ACTIVITIES
Construction/capital expenditures		(48,683)	(37,345)
Allowance for equity funds used during construction		1,002	456
Payments to Acquire Property, Plant, and Equipment		0	(236,978)
Payments to Acquire Businesses and Interest in Affiliates		0	(38)
Change in money pool receivable - net		(1,745)	12,787
Payments to storm reserve escrow account		(235)	(206)
Receipts from storm reserve escrow account		0	3
Changes in securitization account		656	3,285
Net cash flow used in investing activities		(49,005)	(258,036)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		0	190,672
Proceeds from Contributions from Parent		0	47,750
Retirement of long-term debt		(5,114)	(77,094)
Dividends paid:
Common stock		(24,150)	(7,000)
Preferred stock		(482)	(482)
Other		462	664
Net cash flow provided by financing activities		(29,284)	154,510
Net decrease in cash and cash equivalents		(41,539)	(64,258)
Cash and cash equivalents at beginning of period		103,068	88,876
Cash and cash equivalents at end of period		61,529	24,618
Cash paid / (received) during the period for:
Interest - net of amount capitalized		10,637	9,435
Income taxes		0	2,500
Entergy Texas [Member]
OPERATING ACTIVITIES
Consolidated net income		31,955	38,620
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		57,484	52,114
Deferred income taxes, investment tax credits, and non-current taxes accrued		(16,766)	(40,175)
Changes in working capital:
Receivables		(15,969)	(37,832)
Fuel inventory		(4,813)	14,129
Accounts payable		24,900	17,883
Taxes accrued		23,064	51,640
Interest accrued		(471)	(2,719)
Deferred fuel costs		6,144	54,066
Other working capital accounts		4,132	2,774
Changes in provisions for estimated losses		83	(2,126)
Changes in other regulatory assets		45,306	43,378
Changes in pensions and other postretirement liabilities		(13,286)	(12,850)
Other Noncash Income (Expense)		(9,366)	(6,727)
Net cash flow provided by operating activities		132,397	172,175
INVESTING ACTIVITIES
Construction/capital expenditures		(155,755)	(185,945)
Allowance for equity funds used during construction		2,992	4,761
Change in money pool receivable - net		681	(7,011)
Changes in securitization account		8,722	8,712
Other		2,431	0
Net cash flow used in investing activities		(140,929)	(179,483)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		0	123,605
Retirement of long-term debt		(38,134)	(36,659)
Change in money pool payable - net		39,222	(22,068)
Dividends paid:
Other		2,328	(3,815)
Net cash flow provided by financing activities		3,416	61,063
Net decrease in cash and cash equivalents		(5,116)	53,755
Cash and cash equivalents at beginning of period		6,181	2,182
Cash and cash equivalents at end of period		1,065	55,937
Cash paid / (received) during the period for:
Interest - net of amount capitalized		42,430	45,056
Income taxes		(1,446)	3,443
System Energy [Member]
OPERATING ACTIVITIES
Consolidated net income		39,697	51,048
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		128,679	123,424
Deferred income taxes, investment tax credits, and non-current taxes accrued		35,498	83,733
Changes in working capital:
Receivables		10,077	3,731
Accounts payable		3,469	(3,200)
Taxes accrued		(10,086)	(60,954)
Interest accrued		(609)	(145)
Other working capital accounts		2,960	(28,319)
Changes in other regulatory assets		(4,904)	(9,844)
Changes in pensions and other postretirement liabilities		(8,116)	(9,071)
Other Noncash Income (Expense)		(25,205)	(13,111)
Net cash flow provided by operating activities		171,460	137,292
INVESTING ACTIVITIES
Construction/capital expenditures		(32,799)	(57,429)
Allowance for equity funds used during construction		2,412	4,331
Change in money pool receivable - net		(54,860)	22,208
Nuclear fuel purchases		(22,510)	(130,275)
Payments for Nuclear Fuel		(22,510)	(130,275)
Proceeds from sale of nuclear fuel		60,188	11,467
Proceeds from nuclear decommissioning trust fund sales		253,487	289,414
Investment in nuclear decommissioning trust funds		(271,901)	(307,465)
Net cash flow used in investing activities		(65,983)	(167,749)
Proceeds from the issuance of:
Retirement of long-term debt		(50,001)	(22,001)
Changes in credit borrowings and commercial paper - net		36,289	99,617
Dividends paid:
Common stock		0	(139,000)
Other		(28)	(26)
Net cash flow provided by financing activities		(13,740)	(61,410)
Net decrease in cash and cash equivalents		91,737	(91,867)
Cash and cash equivalents at beginning of period		245,863	230,661
Cash and cash equivalents at end of period		337,600	138,794
Cash paid / (received) during the period for:
Interest - net of amount capitalized		17,656	18,494
Income taxes		$ 0	$ 3,402
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2017 and 2016 include $6.9 million and $10.6 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Cash and cash equivalents:
Cash	$ 67,238	$ 129,579
Temporary cash investments	867,257	1,058,265
Total cash and cash equivalents	934,495	1,187,844
Accounts receivable:
Customer	579,674	654,995
Allowance for doubtful accounts	(12,947)	(11,924)
Other	138,285	158,419
Accrued unbilled revenues	415,424	368,677
Total accounts receivable	1,120,436	1,170,167
Deferred fuel costs	194,245	108,465
Fuel inventory - at average cost	173,387	179,600
Materials and supplies - at average cost	695,690	698,523
Deferred nuclear refueling outage costs	228,300	146,221
Prepayments and other	252,791	193,448
TOTAL	3,599,344	3,684,268
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	198	198
Decommissioning trust funds	6,796,911	5,723,897
Non-utility property - at cost (less accumulated depreciation)	247,363	233,641
Other	453,705	469,664
TOTAL	7,498,177	6,427,400
PROPERTY, PLANT, AND EQUIPMENT
Electric	45,916,902	45,191,216
Property under capital lease	618,731	619,527
Natural gas	426,674	413,224
Construction work in progress	1,741,867	1,378,180
Nuclear fuel	958,190	1,037,899
TOTAL PROPERTY, PLANT, AND EQUIPMENT	49,662,364	48,640,046
Less - accumulated depreciation and amortization	21,095,139	20,718,639
PROPERTY, PLANT, AND EQUIPMENT - NET	28,567,225	27,921,407
Regulatory assets:
Regulatory asset for income taxes - net	769,364	761,280
Other regulatory assets	4,699,217	4,769,913
Deferred fuel costs	239,199	239,100
Goodwill	377,172	377,172
Accumulated deferred income taxes	115,562	117,885
Other	141,777	1,606,009
TOTAL	6,342,291	7,871,359
TOTAL ASSETS	46,007,037	45,904,434
CURRENT LIABILITIES
Currently maturing long-term debt	702,909	364,900
Notes payable and commercial paper	1,248,969	415,011
Accounts payable	1,165,699	1,285,577
Customer deposits	401,089	403,311
Taxes Payable, Current	178,912	181,114
Interest accrued	183,282	187,229
Deferred fuel costs	60,687	102,753
Obligations under capital leases	2,387	2,423
Pension and other postretirement liabilities	72,127	76,942
Other	224,469	180,836
TOTAL	4,240,530	3,200,096
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	7,246,612	7,495,290
Accumulated deferred investment tax credits	221,449	227,147
Obligations under capital leases	23,179	24,582
Other regulatory liabilities	1,564,679	1,572,929
Decommissioning and asset retirement cost liabilities	6,118,860	5,992,476
Accumulated provisions	474,020	481,636
Pension and other postretirement liabilities	2,860,479	3,036,010
Long-term debt	14,307,759	14,467,655
Other	375,429	1,121,619
TOTAL	33,192,466	34,419,344
Subsidiaries' preferred stock without sinking fund	203,185	203,185
Common Shareholders' Equity:
Common stock	2,548	2,548
Paid-in capital	5,409,862	5,417,245
Retained earnings	8,375,890	8,195,571
Accumulated other comprehensive income (loss)	52,773	(34,971)
Less - treasury stock, at cost	5,470,217	5,498,584
TOTAL	8,370,856	8,081,809
TOTAL	8,370,856	8,081,809
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	46,007,037	45,904,434
Entergy Arkansas [Member]
Cash and cash equivalents:
Cash	2,741	20,174
Temporary cash investments	336	335
Total cash and cash equivalents	3,077	20,509
Securitization recovery trust account	3,569	4,140
Accounts receivable:
Customer	96,720	102,229
Allowance for doubtful accounts	(1,084)	(1,211)
Associated companies	36,015	35,286
Other	40,672	58,153
Accrued unbilled revenues	110,235	100,193
Total accounts receivable	282,558	294,650
Deferred fuel costs	145,033	96,690
Fuel inventory - at average cost	34,362	32,760
Materials and supplies - at average cost	182,839	182,600
Deferred nuclear refueling outage costs	109,546	81,313
Prepayments and other	19,691	14,293
TOTAL	780,675	726,955
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	884,308	834,735
Other	5,536	7,912
TOTAL	889,844	842,647
PROPERTY, PLANT, AND EQUIPMENT
Electric	10,726,461	10,488,060
Property under capital lease	637	716
Construction work in progress	328,037	304,073
Nuclear fuel	259,901	307,352
TOTAL PROPERTY, PLANT, AND EQUIPMENT	11,315,036	11,100,201
Less - accumulated depreciation and amortization	4,666,137	4,635,885
PROPERTY, PLANT, AND EQUIPMENT - NET	6,648,899	6,464,316
Regulatory assets:
Regulatory asset for income taxes - net	66,024	62,646
Other regulatory assets	1,430,243	1,428,029
Deferred fuel costs	66,997	66,898
Other	16,577	14,626
TOTAL	1,579,841	1,572,199
TOTAL ASSETS	9,899,259	9,606,117
CURRENT LIABILITIES
Currently maturing long-term debt	114,700	114,700
Short-term borrowings	14,696	0
Associated companies accounts payable	152,723	239,711
Other	204,921	185,153
Customer deposits	97,425	97,512
Taxes Payable, Current	8,131	7,194
Interest accrued	18,396	16,580
Other	36,150	36,557
TOTAL	647,142	697,407
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	2,224,030	2,186,623
Accumulated deferred investment tax credits	34,704	35,305
Other regulatory liabilities	330,797	305,907
Decommissioning and asset retirement cost liabilities	952,353	924,353
Accumulated provisions	26,139	18,682
Pension and other postretirement liabilities	383,543	424,234
Long-term debt	2,949,561	2,715,085
Other	14,183	13,854
TOTAL	6,915,310	6,624,043
Subsidiaries' preferred stock without sinking fund	31,350	31,350
Common Shareholders' Equity:
Common stock	470	470
Paid-in capital	790,243	790,243
Retained earnings	1,514,744	1,462,604
TOTAL	2,305,457	2,253,317
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	9,899,259	9,606,117
Entergy Louisiana [Member]
Cash and cash equivalents:
Cash	3,419	49,972
Temporary cash investments	211,864	163,878
Total cash and cash equivalents	215,283	213,850
Accounts receivable:
Customer	222,291	213,517
Allowance for doubtful accounts	(7,459)	(6,277)
Associated companies	173,665	155,794
Other	44,855	54,186
Accrued unbilled revenues	170,863	159,176
Total accounts receivable	604,215	576,396
Deferred fuel costs	25,902	0
Fuel inventory - at average cost	46,204	50,738
Materials and supplies - at average cost	289,985	294,421
Deferred nuclear refueling outage costs	94,772	22,535
Prepaid Taxes	57,418	110,104
Prepayments and other	59,527	41,687
TOTAL	1,393,306	1,309,731
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	1,390,587	1,390,587
Decommissioning trust funds	1,220,699	1,140,707
Non-utility property - at cost (less accumulated depreciation)	231,512	217,494
Storm Reserve Escrow Account	283,451	291,485
Other	24,481	28,844
TOTAL	3,150,730	3,069,117
PROPERTY, PLANT, AND EQUIPMENT
Electric	19,117,749	18,827,532
Natural gas	178,932	172,816
Construction work in progress	919,336	670,201
Nuclear fuel	361,502	249,807
TOTAL PROPERTY, PLANT, AND EQUIPMENT	20,577,519	19,920,356
Less - accumulated depreciation and amortization	8,530,511	8,420,596
PROPERTY, PLANT, AND EQUIPMENT - NET	12,047,008	11,499,760
Regulatory assets:
Regulatory asset for income taxes - net	475,836	470,480
Other regulatory assets	1,122,991	1,168,058
Deferred fuel costs	168,122	168,122
Other	20,420	16,003
TOTAL	1,787,369	1,822,663
TOTAL ASSETS	18,378,413	17,701,271
CURRENT LIABILITIES
Currently maturing long-term debt	517,706	200,198
Short-term borrowings	34,490	3,794
Associated companies accounts payable	75,909	82,106
Other	334,472	358,741
Customer deposits	146,633	148,601
Interest accrued	72,715	75,598
Deferred fuel costs	0	48,211
Other	101,702	80,013
TOTAL	1,283,627	997,262
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	2,910,546	2,691,118
Accumulated deferred investment tax credits	124,306	126,741
Other regulatory liabilities	816,681	880,974
Decommissioning and asset retirement cost liabilities	1,111,194	1,082,685
Accumulated provisions	304,664	310,772
Pension and other postretirement liabilities	741,841	780,278
Long-term debt	5,728,309	5,612,593
Other	148,536	137,039
TOTAL	11,886,077	11,622,200
Common Shareholders' Equity:
Accumulated other comprehensive income (loss)	(49,122)	(48,442)
Members' Equity	5,257,831	5,130,251
TOTAL	5,208,709	5,081,809
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	18,378,413	17,701,271
Entergy Mississippi [Member]
Cash and cash equivalents:
Cash	715	16
Temporary cash investments	7	76,818
Total cash and cash equivalents	722	76,834
Accounts receivable:
Customer	57,539	51,218
Allowance for doubtful accounts	(540)	(549)
Associated companies	34,939	45,973
Other	8,223	12,006
Accrued unbilled revenues	57,170	51,327
Total accounts receivable	157,331	159,975
Deferred fuel costs	20,579	6,957
Fuel inventory - at average cost	44,560	50,872
Materials and supplies - at average cost	42,065	41,146
Prepayments and other	15,742	8,873
TOTAL	280,999	344,657
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,600	4,608
Escrow accounts	31,875	31,783
TOTAL	36,475	36,391
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,409,179	4,321,214
Property under capital lease	873	1,590
Construction work in progress	176,623	118,182
TOTAL PROPERTY, PLANT, AND EQUIPMENT	4,586,675	4,440,986
Less - accumulated depreciation and amortization	1,626,005	1,602,711
PROPERTY, PLANT, AND EQUIPMENT - NET	2,960,670	2,838,275
Regulatory assets:
Regulatory asset for income taxes - net	39,337	38,284
Other regulatory assets	368,118	342,213
Other	3,549	2,320
TOTAL	411,004	382,817
TOTAL ASSETS	3,689,148	3,602,140
CURRENT LIABILITIES
Associated companies accounts payable	99,489	43,647
Other	73,037	80,227
Customer deposits	83,928	84,112
Taxes Payable, Current	42,679	64,040
Interest accrued	21,693	21,653
Other	15,465	9,554
TOTAL	336,291	303,233
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	892,081	861,331
Accumulated deferred investment tax credits	8,587	8,667
Decommissioning and asset retirement cost liabilities	8,967	8,722
Accumulated provisions	47,741	54,440
Pension and other postretirement liabilities	98,865	109,551
Long-term debt	1,121,356	1,120,916
Other	15,104	20,108
TOTAL	2,192,701	2,183,735
Subsidiaries' preferred stock without sinking fund	20,381	20,381
Common Shareholders' Equity:
Common stock	199,326	199,326
Paid-in capital	167	167
Retained earnings	940,282	895,298
TOTAL	1,139,775	1,094,791
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	3,689,148	3,602,140
Entergy New Orleans [Member]
Cash and cash equivalents:
Cash	862	28
Temporary cash investments	60,667	103,040
Total cash and cash equivalents	61,529	103,068
Securitization recovery trust account	1,082	1,738
Accounts receivable:
Customer	47,162	43,536
Allowance for doubtful accounts	(3,074)	(3,059)
Associated companies	18,045	16,811
Other	6,891	5,926
Accrued unbilled revenues	20,168	18,254
Total accounts receivable	89,192	81,468
Deferred fuel costs	2,731	4,818
Fuel inventory - at average cost	2,306	1,841
Materials and supplies - at average cost	10,494	8,416
Prepaid Taxes	4,341	4,379
Prepayments and other	20,353	6,587
TOTAL	192,028	212,315
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	1,016	1,016
Storm Reserve Escrow Account	81,672	81,437
Other	4,787	7,160
TOTAL	87,475	89,613
PROPERTY, PLANT, AND EQUIPMENT
Electric	1,262,714	1,258,934
Natural gas	247,742	240,408
Construction work in progress	38,314	24,975
TOTAL PROPERTY, PLANT, AND EQUIPMENT	1,548,770	1,524,317
Less - accumulated depreciation and amortization	610,405	604,825
PROPERTY, PLANT, AND EQUIPMENT - NET	938,365	919,492
Regulatory assets:
Other regulatory assets	265,387	268,106
Deferred fuel costs	4,080	4,080
Other	1,522	963
TOTAL	270,989	273,149
TOTAL ASSETS	1,488,857	1,494,569
CURRENT LIABILITIES
Current payable due Entergy Louisiana	2,104	2,104
Associated companies accounts payable	41,981	39,260
Other	23,206	35,920
Customer deposits	28,773	28,667
Interest accrued	4,974	5,443
Other	13,006	11,415
TOTAL	114,044	122,809
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	352,001	334,953
Accumulated deferred investment tax credits	559	622
Regulatory liability for income taxes - net	5,844	9,074
Decommissioning and asset retirement cost liabilities	2,974	2,875
Accumulated provisions	86,719	88,513
Pension and other postretirement liabilities	28,701	36,750
Long-term debt	423,632	428,467
Gas system rebuild insurance proceeds	0	447
Long-term payable due to Entergy Louisiana	18,423	18,423
Other	8,006	4,910
TOTAL	926,859	925,034
Subsidiaries' preferred stock without sinking fund	19,780	19,780
Common Shareholders' Equity:
Common stock	33,744	33,744
Paid-in capital	171,544	171,544
Retained earnings	222,886	221,658
TOTAL	428,174	426,946
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	1,488,857	1,494,569
Entergy Texas [Member]
Cash and cash equivalents:
Cash	1,036	1,216
Temporary cash investments	29	4,965
Total cash and cash equivalents	1,065	6,181
Securitization recovery trust account	28,729	37,451
Accounts receivable:
Customer	70,008	71,803
Allowance for doubtful accounts	(791)	(828)
Associated companies	40,867	39,447
Other	13,121	14,756
Accrued unbilled revenues	56,988	39,727
Total accounts receivable	180,193	164,905
Fuel inventory - at average cost	41,990	37,177
Materials and supplies - at average cost	38,807	36,631
Prepayments and other	14,585	18,599
TOTAL	305,369	300,944
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	573	600
Non-utility property - at cost (less accumulated depreciation)	376	376
Other	19,018	18,801
TOTAL	19,967	19,777
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,367,085	4,274,069
Construction work in progress	135,733	111,227
TOTAL PROPERTY, PLANT, AND EQUIPMENT	4,502,818	4,385,296
Less - accumulated depreciation and amortization	1,542,664	1,526,057
PROPERTY, PLANT, AND EQUIPMENT - NET	2,960,154	2,859,239
Regulatory assets:
Regulatory asset for income taxes - net	105,086	105,816
Other regulatory assets	695,580	740,156
Other	8,674	7,149
TOTAL	809,340	853,121
TOTAL ASSETS	4,094,830	4,033,081
CURRENT LIABILITIES
Associated companies accounts payable	86,811	47,867
Other	108,341	77,342
Customer deposits	44,329	44,419
Taxes Payable, Current	38,415	15,351
Interest accrued	25,506	25,977
Deferred fuel costs	60,687	54,543
Other	11,753	9,388
TOTAL	375,842	274,887
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	1,008,466	1,027,647
Accumulated deferred investment tax credits	12,459	12,934
Other regulatory liabilities	5,574	8,502
Decommissioning and asset retirement cost liabilities	6,650	6,470
Accumulated provisions	7,667	7,584
Pension and other postretirement liabilities	54,043	67,313
Long-term debt	1,471,091	1,508,407
Other	52,089	50,343
TOTAL	2,618,039	2,689,200
Common Shareholders' Equity:
Common stock	49,452	49,452
Paid-in capital	481,994	481,994
Retained earnings	569,503	537,548
TOTAL	1,100,949	1,068,994
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	4,094,830	4,033,081
System Energy [Member]
Cash and cash equivalents:
Cash	555	786
Temporary cash investments	337,045	245,077
Total cash and cash equivalents	337,600	245,863
Accounts receivable:
Associated companies	147,497	104,390
Other	5,313	3,637
Total accounts receivable	152,810	108,027
Materials and supplies - at average cost	84,418	82,469
Deferred nuclear refueling outage costs	15,867	24,729
Prepaid Taxes	25,968	15,882
Prepayments and other	8,183	4,229
TOTAL	624,846	481,199
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	839,385	780,496
TOTAL	839,385	780,496
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,304,301	4,331,668
Property under capital lease	585,084	585,084
Construction work in progress	61,617	43,888
Nuclear fuel	199,686	259,635
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,150,688	5,220,275
Less - accumulated depreciation and amortization	3,125,020	3,063,249
PROPERTY, PLANT, AND EQUIPMENT - NET	2,025,668	2,157,026
Regulatory assets:
Regulatory asset for income taxes - net	88,924	93,127
Other regulatory assets	420,319	411,212
Other	4,492	4,652
TOTAL	513,735	508,991
TOTAL ASSETS	4,003,634	3,927,712
CURRENT LIABILITIES
Currently maturing long-term debt	3	50,003
Short-term borrowings	53,182	66,893
Associated companies accounts payable	6,719	5,843
Other	48,251	50,558
Interest accrued	13,440	14,049
Other	2,958	2,957
TOTAL	124,553	190,303
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	1,142,955	1,112,865
Accumulated deferred investment tax credits	39,686	41,663
Other regulatory liabilities	406,570	370,862
Decommissioning and asset retirement cost liabilities	845,001	854,202
Pension and other postretirement liabilities	109,734	117,850
Long-term debt	551,293	501,129
Other	5,322	15
TOTAL	3,100,561	2,998,586
Common Shareholders' Equity:
Common stock	679,350	679,350
Retained earnings	99,170	59,473
TOTAL	778,520	738,823
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$ 4,003,634	$ 3,927,712

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Securitization property	$ 550,077	$ 600,996
Securitization bonds	$ 601,861	$ 661,175
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	75,233,350	75,623,363
Entergy Arkansas [Member]
Securitization property	$ 35,365	$ 41,164
Securitization bonds	$ 41,502	$ 48,139
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	$ 83,050	$ 92,951
Securitization bonds	$ 89,364	$ 99,217
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	$ 77,936	$ 82,272
Securitization bonds	$ 79,784	$ 84,776
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	$ 353,726	$ 384,609
Securitization bonds	$ 391,212	$ 429,043
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares issued	46,525,000	46,525,000
Common stock, shares outstanding	46,525,000	46,525,000
System Energy [Member]
Common stock, shares authorized	1,000,000	1,000,000
Common stock, shares issued	789,350	789,350
Common stock, shares outstanding	789,350	789,350

Consolidated Statements Of Chan

Consolidated Statements Of Changes In Equity - USD ($) $ in Thousands	Total		Subsidiaries Preferred Stock [Member]		Paid In Capital [Member]	Retained Earnings [Member]		Accumulated Other Comprehensive Income [Member]	Common Stock [Member]	Treasury Stock [Member]	Entergy Arkansas [Member]	Entergy Arkansas [Member]Paid In Capital [Member]	Entergy Arkansas [Member]Retained Earnings [Member]	Entergy Arkansas [Member]Common Stock [Member]	Entergy Louisiana [Member]	Entergy Louisiana [Member]Member's Equity [Member]	Entergy Louisiana [Member]Accumulated Other Comprehensive Income [Member]	Entergy Mississippi [Member]	Entergy Mississippi [Member]Capital Stock Expense and Other [Member]	Entergy Mississippi [Member]Retained Earnings [Member]	Entergy Mississippi [Member]Common Stock [Member]	Entergy New Orleans [Member]	Entergy New Orleans [Member]Paid In Capital [Member]	Entergy New Orleans [Member]Retained Earnings [Member]	Entergy New Orleans [Member]Common Stock [Member]	Entergy Texas [Member]	Entergy Texas [Member]Paid In Capital [Member]	Entergy Texas [Member]Retained Earnings [Member]	Entergy Texas [Member]Common Stock [Member]	System Energy [Member]	System Energy [Member]Retained Earnings [Member]	System Energy [Member]Common Stock [Member]
Beginning Balance at Dec. 31, 2015	$ 9,256,791		$ 0		$ 5,403,758	$ 9,393,913		$ 8,951	$ 2,548	$ (5,552,379)	$ 1,891,658	$ 588,493	$ 1,302,695	$ 470	$ 4,737,312	$ 4,793,724	$ (56,412)	$ 1,012,050	$ (690)	$ 813,414	$ 199,326	$ 350,032	$ 123,794	$ 192,494	$ 33,744	$ 961,456	$ 481,994	$ 430,010	$ 49,452	$ 781,079	$ 61,729	$ 719,350
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Consolidated net income	807,832	[1]	10,552	[1]	0	797,280	[1]	0	0	0	53,185	0	53,185	0	364,931	364,931	0	49,312	0	49,312	0	23,010	0	23,010	0	38,620	0	38,620	0	51,048	51,048	0
Other comprehensive income (loss)	(18,106)		0		0	0		(18,106)	0	0					(493)	0	(493)
Common stock issuances related to stock plans	25,665		0		(11,212)	0		0	0	36,877
Common stock dividends declared	(303,843)		0		0	(303,843)		0	0	0					(105,500)	(105,500)	0	(24,000)	0	(24,000)	0	(7,000)	0	(7,000)	0					(139,000)	(99,000)	(40,000)
Proceeds from Contributions from Parent											200,000	200,000	0	0								47,750	47,750	0	0
Preferred dividend requirements of subsidiaries	(10,552)	[1]	(10,552)	[1]	0	0		0	0	0	(3,437)	0	(3,437)	0				(1,414)	0	(1,414)	0	(482)	0	(482)	0
Other															(15)	(15)	0
Ending Balance at Jun. 30, 2016	9,757,787		0		5,392,546	9,887,350		(9,155)	2,548	(5,515,502)	2,141,406	788,493	1,352,443	470	4,996,235	5,053,140	(56,905)	1,035,948	(690)	837,312	199,326	413,310	171,544	208,022	33,744	1,000,076	481,994	468,630	49,452	693,127	13,777	679,350
Beginning Balance at Dec. 31, 2016	8,081,809		0		5,417,245	8,195,571		(34,971)	2,548	(5,498,584)	2,253,317	790,243	1,462,604	470	5,081,809	5,130,251	(48,442)	1,094,791	167	895,298	199,326	426,946	171,544	221,658	33,744	1,068,994	481,994	537,548	49,452	738,823	59,473	679,350
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Consolidated net income	499,420	[1]	6,892	[1]	0	492,528	[1]	0	0	0	52,854	0	52,854	0	218,857	218,857	0	45,461	0	45,461	0	25,860	0	25,860	0	31,955	0	31,955	0	39,697	39,697	0
Other comprehensive income (loss)	87,744		0		0	0		87,744	0	0					(680)	0	(680)
Common stock issuances related to stock plans	20,984		0		(7,383)	0		0	0	28,367
Common stock dividends declared	(312,209)		0		0	(312,209)		0	0	0					(91,250)	(91,250)	0					(24,150)	0	(24,150)	0
Proceeds from Contributions from Parent											0											0
Preferred dividend requirements of subsidiaries	(6,892)	[1]	(6,892)	[1]	0	0		0	0	0	(714)	0	(714)	0				(477)	0	(477)	0	(482)	0	(482)	0
Other															(27)	(27)	0
Ending Balance at Jun. 30, 2017	$ 8,370,856		$ 0		$ 5,409,862	$ 8,375,890		$ 52,773	$ 2,548	$ (5,470,217)	$ 2,305,457	$ 790,243	$ 1,514,744	$ 470	$ 5,208,709	$ 5,257,831	$ (49,122)	$ 1,139,775	$ 167	$ 940,282	$ 199,326	$ 428,174	$ 171,544	$ 222,886	$ 33,744	$ 1,100,949	$ 481,994	$ 569,503	$ 49,452	$ 778,520	$ 99,170	$ 679,350
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2017 and 2016 include $6.9 million and $10.6 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Consolidated Statements Of Cha7

Consolidated Statements Of Changes In Equity (Parenthetical) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Statement of Stockholders' Equity [Abstract]
Preferred dividends on subsidiaries' preferred stock	$ 6.9	$ 10.6

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017		Jun. 30, 2016
Net income	$ 413,368	$ 572,590	$ 499,420	[1]	$ 807,832	[1]
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss)	19,949	(64,041)	19,421		(73,547)
Pension and other postretirement liabilities	10,916	5,043	19,548		12,605
Net unrealized investment gains	11,696	20,955	49,523		44,024
Foreign currency translation	(748)	(904)	(748)		(1,188)
Other comprehensive income (loss)	41,813	(38,947)	87,744		(18,106)
Total comprehensive income	455,181	533,643	587,164		789,726
Preferred dividend requirements of subsidiaries	3,446	5,276	6,892	[1]	10,552	[1]
Comprehensive Income Attributable to Entergy Corporation	451,735	528,367	580,272		779,174
Entergy Louisiana [Member]
Net income	124,479	253,325	218,857		364,931
Other comprehensive income (loss)
Pension and other postretirement liabilities	(310)	(230)	(680)		(493)
Other comprehensive income (loss)	(310)	(230)	(680)		(493)
Total comprehensive income	$ 124,169	$ 253,095	$ 218,177		$ 364,438
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2017 and 2016 include $6.9 million and $10.6 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Consolidated Statements Of Com9

Consolidated Statements Of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Tax	$ 10,684	$ (34,576)	$ 10,325	$ (39,777)
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Tax	5,839	2,779	12,216	3,037
Other Comprehensive Income (Loss), Available-for-sale Securities, Tax	2,870	19,515	42,164	37,873
Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Tax	(403)	(487)	(403)	(640)
Entergy Louisiana [Member]
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Tax	$ (292)	$ (144)	$ (524)	$ (259)

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2017
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Planned Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s planned shutdown of Pilgrim no later than June 1, 2019. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. As discussed in the Form 10-K, 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. Entergy Louisiana received payment from the U.S. Treasury in August 2016. In September 2016 the U.S. Court of Federal Claims issued a further judgment in the River Bend case in the amount of $5 million . Entergy Louisiana received payment from the U.S. Treasury in January 2017. As discussed in the Form 10-K, in September 2016 the U.S. Court of Federal Claims issued a judgment in the Entergy Nuclear Palisades case in the amount of $14 million , including $11 million related to costs previously capitalized and $3 million related to costs previously recorded as other operation and maintenance expense. Entergy Nuclear Palisades recorded a receivable for that amount, and subsequently received payment from the U.S. Treasury in January 2017. As discussed in the Form 10-K, in October 2016 the U.S. Court of Federal Claims issued a judgment in the second round Entergy Nuclear Indian Point 2 case in the amount of $34 million , including $14 million related to costs previously capitalized, $15 million related to costs previously recorded as other operation and maintenance expense, $3 million related to previously recorded decommissioning expense, and $2 million related to costs previously recorded as taxes other than income taxes. Entergy Nuclear Indian Point 2 recorded a receivable for that amount, and subsequently received payment from the U.S. Treasury in January 2017. 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 and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Entergy Arkansas [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Planned Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s planned shutdown of Pilgrim no later than June 1, 2019. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. As discussed in the Form 10-K, 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. Entergy Louisiana received payment from the U.S. Treasury in August 2016. In September 2016 the U.S. Court of Federal Claims issued a further judgment in the River Bend case in the amount of $5 million . Entergy Louisiana received payment from the U.S. Treasury in January 2017. As discussed in the Form 10-K, in September 2016 the U.S. Court of Federal Claims issued a judgment in the Entergy Nuclear Palisades case in the amount of $14 million , including $11 million related to costs previously capitalized and $3 million related to costs previously recorded as other operation and maintenance expense. Entergy Nuclear Palisades recorded a receivable for that amount, and subsequently received payment from the U.S. Treasury in January 2017. As discussed in the Form 10-K, in October 2016 the U.S. Court of Federal Claims issued a judgment in the second round Entergy Nuclear Indian Point 2 case in the amount of $34 million , including $14 million related to costs previously capitalized, $15 million related to costs previously recorded as other operation and maintenance expense, $3 million related to previously recorded decommissioning expense, and $2 million related to costs previously recorded as taxes other than income taxes. Entergy Nuclear Indian Point 2 recorded a receivable for that amount, and subsequently received payment from the U.S. Treasury in January 2017. 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 and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Entergy Louisiana [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Planned Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s planned shutdown of Pilgrim no later than June 1, 2019. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. As discussed in the Form 10-K, 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. Entergy Louisiana received payment from the U.S. Treasury in August 2016. In September 2016 the U.S. Court of Federal Claims issued a further judgment in the River Bend case in the amount of $5 million . Entergy Louisiana received payment from the U.S. Treasury in January 2017. As discussed in the Form 10-K, in September 2016 the U.S. Court of Federal Claims issued a judgment in the Entergy Nuclear Palisades case in the amount of $14 million , including $11 million related to costs previously capitalized and $3 million related to costs previously recorded as other operation and maintenance expense. Entergy Nuclear Palisades recorded a receivable for that amount, and subsequently received payment from the U.S. Treasury in January 2017. As discussed in the Form 10-K, in October 2016 the U.S. Court of Federal Claims issued a judgment in the second round Entergy Nuclear Indian Point 2 case in the amount of $34 million , including $14 million related to costs previously capitalized, $15 million related to costs previously recorded as other operation and maintenance expense, $3 million related to previously recorded decommissioning expense, and $2 million related to costs previously recorded as taxes other than income taxes. Entergy Nuclear Indian Point 2 recorded a receivable for that amount, and subsequently received payment from the U.S. Treasury in January 2017. 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 and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Entergy Mississippi [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Planned Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s planned shutdown of Pilgrim no later than June 1, 2019. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. As discussed in the Form 10-K, 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. Entergy Louisiana received payment from the U.S. Treasury in August 2016. In September 2016 the U.S. Court of Federal Claims issued a further judgment in the River Bend case in the amount of $5 million . Entergy Louisiana received payment from the U.S. Treasury in January 2017. As discussed in the Form 10-K, in September 2016 the U.S. Court of Federal Claims issued a judgment in the Entergy Nuclear Palisades case in the amount of $14 million , including $11 million related to costs previously capitalized and $3 million related to costs previously recorded as other operation and maintenance expense. Entergy Nuclear Palisades recorded a receivable for that amount, and subsequently received payment from the U.S. Treasury in January 2017. As discussed in the Form 10-K, in October 2016 the U.S. Court of Federal Claims issued a judgment in the second round Entergy Nuclear Indian Point 2 case in the amount of $34 million , including $14 million related to costs previously capitalized, $15 million related to costs previously recorded as other operation and maintenance expense, $3 million related to previously recorded decommissioning expense, and $2 million related to costs previously recorded as taxes other than income taxes. Entergy Nuclear Indian Point 2 recorded a receivable for that amount, and subsequently received payment from the U.S. Treasury in January 2017. 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 and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Entergy New Orleans [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Planned Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s planned shutdown of Pilgrim no later than June 1, 2019. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. As discussed in the Form 10-K, 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. Entergy Louisiana received payment from the U.S. Treasury in August 2016. In September 2016 the U.S. Court of Federal Claims issued a further judgment in the River Bend case in the amount of $5 million . Entergy Louisiana received payment from the U.S. Treasury in January 2017. As discussed in the Form 10-K, in September 2016 the U.S. Court of Federal Claims issued a judgment in the Entergy Nuclear Palisades case in the amount of $14 million , including $11 million related to costs previously capitalized and $3 million related to costs previously recorded as other operation and maintenance expense. Entergy Nuclear Palisades recorded a receivable for that amount, and subsequently received payment from the U.S. Treasury in January 2017. As discussed in the Form 10-K, in October 2016 the U.S. Court of Federal Claims issued a judgment in the second round Entergy Nuclear Indian Point 2 case in the amount of $34 million , including $14 million related to costs previously capitalized, $15 million related to costs previously recorded as other operation and maintenance expense, $3 million related to previously recorded decommissioning expense, and $2 million related to costs previously recorded as taxes other than income taxes. Entergy Nuclear Indian Point 2 recorded a receivable for that amount, and subsequently received payment from the U.S. Treasury in January 2017. 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 and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Entergy Texas [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Planned Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s planned shutdown of Pilgrim no later than June 1, 2019. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. As discussed in the Form 10-K, 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. Entergy Louisiana received payment from the U.S. Treasury in August 2016. In September 2016 the U.S. Court of Federal Claims issued a further judgment in the River Bend case in the amount of $5 million . Entergy Louisiana received payment from the U.S. Treasury in January 2017. As discussed in the Form 10-K, in September 2016 the U.S. Court of Federal Claims issued a judgment in the Entergy Nuclear Palisades case in the amount of $14 million , including $11 million related to costs previously capitalized and $3 million related to costs previously recorded as other operation and maintenance expense. Entergy Nuclear Palisades recorded a receivable for that amount, and subsequently received payment from the U.S. Treasury in January 2017. As discussed in the Form 10-K, in October 2016 the U.S. Court of Federal Claims issued a judgment in the second round Entergy Nuclear Indian Point 2 case in the amount of $34 million , including $14 million related to costs previously capitalized, $15 million related to costs previously recorded as other operation and maintenance expense, $3 million related to previously recorded decommissioning expense, and $2 million related to costs previously recorded as taxes other than income taxes. Entergy Nuclear Indian Point 2 recorded a receivable for that amount, and subsequently received payment from the U.S. Treasury in January 2017. 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 and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
System Energy [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Planned Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s planned shutdown of Pilgrim no later than June 1, 2019. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. As discussed in the Form 10-K, 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. Entergy Louisiana received payment from the U.S. Treasury in August 2016. In September 2016 the U.S. Court of Federal Claims issued a further judgment in the River Bend case in the amount of $5 million . Entergy Louisiana received payment from the U.S. Treasury in January 2017. As discussed in the Form 10-K, in September 2016 the U.S. Court of Federal Claims issued a judgment in the Entergy Nuclear Palisades case in the amount of $14 million , including $11 million related to costs previously capitalized and $3 million related to costs previously recorded as other operation and maintenance expense. Entergy Nuclear Palisades recorded a receivable for that amount, and subsequently received payment from the U.S. Treasury in January 2017. As discussed in the Form 10-K, in October 2016 the U.S. Court of Federal Claims issued a judgment in the second round Entergy Nuclear Indian Point 2 case in the amount of $34 million , including $14 million related to costs previously capitalized, $15 million related to costs previously recorded as other operation and maintenance expense, $3 million related to previously recorded decommissioning expense, and $2 million related to costs previously recorded as taxes other than income taxes. Entergy Nuclear Indian Point 2 recorded a receivable for that amount, and subsequently received payment from the U.S. Treasury in January 2017. 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 and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.

Rate And Regulatory Matters

Rate And Regulatory Matters	6 Months Ended
	Jun. 30, 2017
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 Energy Cost Recovery Rider In March 2017, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01164 per kWh to $0.01547 per kWh. The APSC staff filed testimony in March 2017 recommending that the redetermined rate should be implemented with the first billing cycle of April 2017 under the normal operation of the tariff. Accordingly, the redetermined rate went into effect on March 31, 2017 pursuant to the tariff. In July 2017 the Arkansas Attorney General requested additional information to support certain of the costs included in Entergy Arkansas’s 2017 energy cost rate redetermination. Entergy Louisiana As discussed in the Form 10-K, in June 2016 the LPSC staff provided notice of audits of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. Discovery commenced in March 2017. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi attorney general filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power. The defendants have denied the allegations. In June 2017 the District Court issued a case management order setting a trial date in November 2018. Discovery is currently in progress. Entergy Texas As discussed in the Form 10-K, 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. In December 2016, Entergy Texas entered into a stipulation and settlement agreement resulting in a $6 million disallowance not associated with any particular issue raised and a refund of the over-recovery balance of $21 million as of November 30, 2016, to most customers beginning April 2017 through June 2017. The fuel reconciliation settlement was approved by the PUCT in March 2017 and the refunds were made. In June 2017, Entergy Texas filed an application for a fuel refund of approximately $30.7 million for the months of December 2016 through April 2017. For most customers, the refunds will flow through bills for the months of July 2017 through September 2017. Also in June 2017, the PUCT’s administrative law judge approved the refund on an interim basis. A final decision in this matter remains pending. 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 2016 Formula Rate Plan Filing As discussed in the Form 10-K, Entergy Arkansas is required to make a supplemental filing supporting the recovery of certain nuclear costs. In April 2017, Entergy Arkansas filed a motion consented to by all parties requesting that it be permitted to submit its supplemental filing in conjunction with its 2017 formula rate plan filing, which was subsequently made in July 2017 and is discussed below. In May 2017 the APSC approved the joint motion and proposal to review Entergy Arkansas’s supplemental filing on a concurrent schedule with the 2017 formula rate plan filing. In doing so, however, the APSC noted that a determination of whether the supplemental information supporting certain nuclear expenditures will be considered in the hearing for the 2017 formula rate plan filing or a separate hearing will be made at a later time. 2017 Formula Rate Plan Filing In July 2017, Entergy Arkansas filed with the APSC its 2017 formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2018 test period to be below the formula rate plan bandwidth. The filing projected a $129.7 million revenue requirement increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . Because the projected revenue increase exceeds the four percent annual revenue constraint for each rate class, however, Entergy Arkansas proposed a $70.9 million revenue requirement increase. Entergy Arkansas requested an order approving its proposed formula rate plan adjustment by December 13, 2017. If a final order is not issued by this date, the proposed formula rate plan adjustment will become effective January 2, 2018, subject to refund. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in September 2016, Entergy Arkansas filed an application seeking a finding from the APSC that Entergy Arkansas’s deployment of advanced metering infrastructure is in the public interest. In June 2017 the APSC staff and Arkansas Attorney General filed direct testimony. The APSC staff generally supported Entergy Arkansas’s AMI deployment conditioned on various recommendations. The Arkansas Attorney General’s consultant primarily recommended denial of Entergy Arkansas’s application but alternatively suggested recommendations in the event the APSC approves Entergy Arkansas’s proposal. Entergy Arkansas filed rebuttal testimony in June 2017, substantially accepting the APSC staff’s recommendations. In August 2017, Entergy Arkansas and the parties to the proceeding filed a joint motion to suspend the procedural schedule pending the filing with the APSC of an agreement in principle on all issues. Filings with the LPSC Retail Rates - Electric 2014 Formula Rate Plan Filing As discussed in the Form 10-K, in September 2015, Entergy Louisiana filed its formula rate plan evaluation report for Entergy Gulf States Louisiana’s and Entergy Louisiana’s 2014 calendar year operations. In June 2017 the LPSC staff and Entergy Louisiana filed an unopposed joint report of proceedings, which was accepted by the LPSC in June 2017, finalizing the results of this proceeding with no changes to rates already implemented. 2015 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. In June 2017 the LPSC staff and Entergy Louisiana filed a joint report of proceedings, which was accepted by the LPSC in June 2017, finalizing the results of the May 2016 evaluation report, interim updates, and corresponding proceedings with no changes to rates already implemented. Also, in November 2016, Entergy Louisiana filed with the LPSC a request to extend the MISO cost recovery mechanism rider provision of its formula rate plan. In March 2017 the LPSC staff submitted direct testimony generally supportive of a one-year extension of the MISO cost recovery mechanism and the intervenor in the proceeding does not oppose an extension for this period of time. In June 2017 an uncontested joint stipulation authorizing a one-year extension of the MISO cost recovery mechanism rider was filed and the LPSC approved the stipulation in July 2017. 2016 Formula Rate Plan Filing In May 2017, Entergy Louisiana filed its formula rate plan evaluation report for its 2016 calendar year operations. The evaluation report reflects an earned return on common equity of 9.84% . As such, no adjustment to base formula rate plan revenue is required. The following adjustments, however, are required under the formula rate plan: The 2016 formula rate plan evaluation report shows a decrease in formula rate plan revenue of approximately $16.9 million , comprised of a decrease in legacy Entergy Louisiana formula rate plan revenue of $3.5 million , a decrease in legacy Entergy Gulf States Louisiana formula rate plan revenue of $9.7 million , and a decrease in incremental formula rate plan revenue of $3.6 million . Additionally, the formula rate plan evaluation report calls for a decrease in the MISO cost recovery revenue requirement of $40.5 million , from the present level of $46.8 million to $6.3 million . Rates reflecting these adjustments will be implemented with the first billing cycle of September 2017, subject to refund, pending the review proceedings. Parties have intervened in the proceedings. No procedural schedule has been established. Waterford 3 Replacement Steam Generator Project See Note 2 to the financial statements in the Form 10-K for discussion of the Waterford 3 replacement steam generator project prudence review proceeding. The refund to customers of approximately $71 million as a result of the settlement approved by the LPSC was made to customers in January 2017. Following a review by the parties, an unopposed joint report of proceedings was filed by the LPSC staff and Entergy Louisiana in May 2017. In May 2017 the LPSC accepted the joint report of proceedings resolving the matter. Union Power Station 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 the decision to deactivate Willow Glen 2 and 4. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three year term permitted by MISO. This matter is pending before an ALJ, with an evidentiary hearing scheduled in August 2017. Retail Rates - Gas 2016 Rate Stabilization Plan Filing In January 2017, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2016. The filing of the evaluation report for test year 2016 reflected an earned return on common equity of 6.37% . As part of the original filing, pursuant to the extraordinary cost provision of the rate stabilization plan, Entergy Louisiana sought to recover approximately $1.5 million in deferred operation and maintenance expenses incurred to restore service and repair damage resulting from flooding and widespread rainfall in southeast Louisiana that occurred in August 2016. Entergy Louisiana requested to recover the prudently incurred August 2016 storm restoration costs over ten years, outside of the rate stabilization plan sharing provisions. As a result, Entergy Louisiana’s filing sought an annual increase in revenue of $1.4 million . Following review of the filing, except for the proposed extraordinary cost recovery, the LPSC staff confirmed Entergy Louisiana’s filing was consistent with the principles and requirements of the rate stabilization plan. The extraordinary cost recovery request associated with the 2016 flood-related deferred operation and maintenance expenses incurred for gas operations was removed from the rate stabilization plan pending LPSC consideration in a separate docket. In April 2017 the LPSC approved a joint report of proceedings and Entergy Louisiana submitted a revised evaluation report reflecting a $1.2 million annual increase in revenue with rates implemented with the first billing cycle of May 2017. In connection with the joint report of proceedings accepted by the LPSC, in May 2017, Entergy Louisiana filed an application to initiate a separate proceeding to recover the deferred operation and maintenance expenses incurred to restore service and repair damage resulting from flooding and widespread rainfall in southeast Louisiana that occurred in August 2016 through the extraordinary cost provision of the gas rate stabilization plan. A procedural schedule has been established, with a hearing in November 2017. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in November 2016, Entergy Louisiana filed an application seeking a finding from the LPSC that Entergy Louisiana’s deployment of advanced electric and gas metering infrastructure is in the public interest. The parties reached an uncontested stipulation permitting implementation of Entergy Louisiana’s proposed AMI system, with modifications to the proposed customer charge. In July 2017 the LPSC approved the stipulation. Filings with the MPSC Formula Rate Plan In March 2017, Entergy Mississippi submitted its formula rate plan 2017 test year filing and 2016 look-back filing showing Entergy Mississippi’s earned return for the historical 2016 calendar year and projected earned return for the 2017 calendar year to be within the formula rate plan bandwidth, resulting in no change in rates. In June 2017, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a stipulation that confirmed that Entergy Mississippi’s earned returns for both the 2016 look-back filing and 2017 test year were within the respective formula rate plan bandwidths. In June 2017 the MPSC approved the stipulation, which resulted in no change in rates. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in November 2016, Entergy Mississippi filed an application seeking a finding from the MPSC that Entergy Mississippi’s deployment of advanced metering infrastructure is in the public interest. In May 2017 the Mississippi Public Utilities Staff and Entergy Mississippi entered into and filed a joint stipulation supporting Entergy Mississippi’s filing, and the MPSC issued an order approving the filing without any material changes, finding that Entergy Mississippi’s deployment of AMI is in the public interest and granting a certificate of public convenience and necessity. The MPSC order also confirmed that Entergy Mississippi shall continue to include in rate base the remaining book value of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Filings with the City Council Retail Rates As discussed in the Form 10-K, in February 2017, Entergy New Orleans filed a proposed implementation plan for the Energy Smart program from April 2017 through March 2020. As part of the proposal, Entergy New Orleans requested that the City Council identify its desired level of funding for the program during this time period and approve a cost recovery mechanism. In April 2017 the City Council approved an implementation plan for the Energy Smart program from April 2017 through December 2019. The City Council directed that the $11.8 million balance reported for Energy Smart funds be used to continue funding the program for Entergy New Orleans’s legacy customers and that the Energy Smart Algiers program continue to be funded through the Algiers fuel adjustment clause, until additional customer funding is required for the legacy customers. The City Council ordered Entergy New Orleans to submit a supplemental and amended implementation plan for program years 8 and 9 of the Energy Smart program (January 2018 through December 2019) in October 2017. Following that filing, the City Council will determine a specific cost recovery mechanism for the program for both legacy and Algiers customers. The City Council will not permit Entergy New Orleans to recover lost contribution to fixed costs for program years 7, 8, or 9 of the Energy Smart program. Internal Restructuring As discussed in the Form 10-K, in July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring that 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 owned by an existing Entergy subsidiary holding company. In May 2017 the City Council adopted a resolution approving the proposed internal restructuring pursuant to an agreement in principle with the City Council advisors and certain intervenors. Pursuant to the agreement in principle, Entergy New Orleans will credit retail customers $10 million in 2017, $1.4 million in the first quarter of the year after the transaction closes, and $117,500 each month in the second year after the transaction closes until such time as new base rates go into effect as a result of the anticipated 2018 base rate case. Entergy New Orleans began crediting retail customers in June 2017. Also pursuant to the agreement in principle, if FERC approval is received prior to December 31, 2018, Entergy New Orleans will provide additional credits to retail customers of $5 million in each of the years 2018, 2019, and 2020. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in October 2016, Entergy New Orleans filed an application seeking a finding from the City Council that Entergy New Orleans’s deployment of advanced electric and gas metering infrastructure is in the public interest. In April 2017, Entergy New Orleans received intervenor testimony that was generally supportive of AMI deployment. The City Council’s advisors filed testimony in May 2017 recommending the adoption of AMI subject to certain modifications, including the denial of Entergy New Orleans’s proposed customer charge as a cost recovery mechanism. In June 2017 the procedural schedule was suspended to allow for settlement discussions. A settlement status conference is scheduled for August 2017. Filings with the PUCT Other Filings In September 2016, Entergy Texas filed with the PUCT a request to amend its transmission cost recovery factor (TCRF) rider. The proposed amended TCRF rider is designed to collect approximately $29.5 million annually from Entergy Texas’s retail customers. This amount includes the approximately $10.5 million annually that Entergy Texas is currently authorized to collect through the TCRF rider. In September 2016 the PUCT suspended the effective date of the tariff change to March 2017. In December 2016, Entergy Texas and the PUCT reached a settlement agreeing to the amended TCRF annual revenue requirement of $29.5 million . The PUCT approved the settlement and issued a final order in March 2017. Entergy Texas implemented the amended TCRF rider beginning with bills covering usage on and after March 20, 2017. In June 2017, Entergy Texas filed an application to amend its distribution cost recovery factor (DCRF) rider by increasing the total collection from $8.65 million to approximately $19 million . In July 2017, Entergy Texas, the PUCT, and the two other parties in the proceeding entered into an unopposed stipulation and settlement agreement resulting in an amended DCRF annual revenue requirement of $18.3 million , with the resulting rates effective for usage no later than October 1, 2017. PUCT action on the stipulation and settlement agreement remains pending. Advanced Metering Infrastructure (AMI) Filing In its most recent regular session, the Texas legislature enacted legislation that extends statutory support for AMI deployment to Entergy Texas and directs that if Entergy Texas elects to deploy AMI, it shall do so as rapidly as practicable. In July 2017, Entergy Texas filed an application seeking an order from the PUCT approving Entergy Texas’s deployment of AMI. Entergy Texas proposed to replace existing meters with advanced meters that enable two-way data communication; design and build a secure and reliable network to support such communications; and implement support systems. AMI is intended to serve as the foundation of Entergy Texas’s modernized power grid. The filing identified a number of quantified and unquantified benefits, with Entergy Texas showing that its AMI deployment is expected to produce nominal net operational cost savings to customers of $33 million . Entergy Texas also sought to continue to include in rate base the remaining book value, approximately $41 million at December 31, 2016, of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Entergy Texas proposed a seven-year depreciable life for the new advanced meters, the three-year deployment of which is expected to begin in 2019. Entergy Texas also proposed a surcharge tariff to recover the reasonable and necessary costs it has and will incur under the deployment plan for the full deployment of advanced meters. Further, Entergy Texas is seeking approval of fees that would be charged to customers who choose to opt out of receiving service through an advanced meter and instead receive electric service with a non-standard meter. Subject to approval by the PUCT, deployment of the communications network is expected to begin in 2018. Entergy Texas expects a decision from the PUCT by December 2017. System Agreement Cost Equalization Proceedings See the Form 10-K for a discussion of the litigation involving the System Agreement at the FERC and in federal courts. Entergy Arkansas Opportunity Sales Proceedings As discussed in the Form 10-K, in June 2009 the LPSC filed a complaint requesting 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 allocated 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 prohibited sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. The LPSC’s complaint challenges sales made beginning in 2002 and requests refunds. In April 2016 the FERC issued orders addressing requests for rehearing filed in July 2012 and an 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 August 2013 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. In May 2016, Entergy Services filed a request for rehearing of the FERC’s April 2016 order addressing the requests for rehearing filed in July 2012. Entergy Services also filed a request for clarification and/or rehearing of the FERC’s April 2016 order addressing the ALJ’s August 2013 initial decision. The APSC and the LPSC also filed requests for rehearing of the FERC’s April 2016 order. The rehearing and clarification requests filed in May 2016 are pending FERC action. Pursuant to the procedural schedule established in the case, Entergy Services re-ran intra-system bills for the ten-year period 2000-2009 to quantify the effects of the FERC's ruling. In November 2016 the LPSC submitted testimony disputing certain aspects of the calculations, and Entergy Services submitted answering testimony in January 2017. In February 2017 the FERC staff filed testimony and Entergy Services filed responsive testimony. In March 2017 the LPSC filed rebuttal testimony. A hearing was held in May 2017. In July 2017, the ALJ issued an initial decision concluding that Entergy Arkansas should pay $86 million plus interest to the other Utility operating companies. The Utility operating companies have the opportunity to challenge the ALJ’s initial decision by filing a brief on exceptions with the FERC. No payments will be made or received by the Utility operating companies until the FERC issues an order reviewing the initial decision and Entergy submits a subsequent filing to comply with that order. The effect of the FERC’s decisions thus far in the case would be that Entergy Arkansas will make payments to some or all of the other Utility operating companies. Because further proceedings will still occur in the case, the amount and recipients of payments by Entergy Arkansas are unknown at this time. Based on testimony previously submitted in the case and its assessment of the April 2016 FERC orders, in the first quarter 2016, Entergy Arkansas recorded a liability of $87 million , which includes interest, for its estimated increased costs and payment to the other Utility operating companies. This estimate is subject to change depending on how the FERC resolves the issues that are still outstanding in the case, including its review of the July 2017 initial decision. 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. Entergy Arkansas, therefore, recorded a regulatory asset in the first quarter 2016 of approximately $75 million , which represents its estimate of the retail portion of the costs. Complaint Against System Energy In January 2017 the APSC and MPSC filed a complaint with the FERC against System Energy. The complaint seeks a reduction in the return on equity component of the Unit Power Sales Agreement pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. Entergy Arkansas also sells some of its Grand Gulf capacity and energy to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans under separate agreements. The current return on equity under the Unit Power Sales Agreement is 10.94% . The complaint alleges that the return on equity is unjust and unreasonable because current capital market and other considerations indicate that it is excessive. The complaint requests the FERC to institute proceedings to investigate the return on equity and establish a lower return on equity, and also requests that the FERC establish January 23, 2017 as a refund effective date. The complaint includes return on equity analysis that purports to establish that the range of reasonable return on equity for System Energy is between 8.37% and 8.67% . System Energy answered the complaint in February 2017 and disputes that a return on equity of 8.37% to 8.67% is just and reasonable. The LPSC and the City Council intervened in the proceeding expressing support for the complaint. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Action by the FERC is pending. Unit Power Sales Agreement In August 2017, System Energy submitted to the FERC proposed amendments to the Unit Power Sales Agreement pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. The filing proposes limited amendments to the Unit Power Sales Agreement to adopt (1) updated rates for use in calculating Grand Gulf plant depreciation and amortization expenses and (2) updated nuclear decommissioning cost annual revenue requirements, both of which are recovered through the Unit Power Sales Agreement rate formula. The proposed amendments would result in lower charges to the Utility operating companies that buy capacity and energy from System Energy under the Unit Power Sales Agreement. The proposed changes are based on updated depreciation and nuclear decommissioning studies that take into account the renewal of Grand Gulf’s operating license for a term through November 1, 2044. System Energy requested that the FERC accept the amendments effective October 1, 2017. Action by the FERC is pending.
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 Energy Cost Recovery Rider In March 2017, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01164 per kWh to $0.01547 per kWh. The APSC staff filed testimony in March 2017 recommending that the redetermined rate should be implemented with the first billing cycle of April 2017 under the normal operation of the tariff. Accordingly, the redetermined rate went into effect on March 31, 2017 pursuant to the tariff. In July 2017 the Arkansas Attorney General requested additional information to support certain of the costs included in Entergy Arkansas’s 2017 energy cost rate redetermination. Entergy Louisiana As discussed in the Form 10-K, in June 2016 the LPSC staff provided notice of audits of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. Discovery commenced in March 2017. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi attorney general filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power. The defendants have denied the allegations. In June 2017 the District Court issued a case management order setting a trial date in November 2018. Discovery is currently in progress. Entergy Texas As discussed in the Form 10-K, 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. In December 2016, Entergy Texas entered into a stipulation and settlement agreement resulting in a $6 million disallowance not associated with any particular issue raised and a refund of the over-recovery balance of $21 million as of November 30, 2016, to most customers beginning April 2017 through June 2017. The fuel reconciliation settlement was approved by the PUCT in March 2017 and the refunds were made. In June 2017, Entergy Texas filed an application for a fuel refund of approximately $30.7 million for the months of December 2016 through April 2017. For most customers, the refunds will flow through bills for the months of July 2017 through September 2017. Also in June 2017, the PUCT’s administrative law judge approved the refund on an interim basis. A final decision in this matter remains pending. 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 2016 Formula Rate Plan Filing As discussed in the Form 10-K, Entergy Arkansas is required to make a supplemental filing supporting the recovery of certain nuclear costs. In April 2017, Entergy Arkansas filed a motion consented to by all parties requesting that it be permitted to submit its supplemental filing in conjunction with its 2017 formula rate plan filing, which was subsequently made in July 2017 and is discussed below. In May 2017 the APSC approved the joint motion and proposal to review Entergy Arkansas’s supplemental filing on a concurrent schedule with the 2017 formula rate plan filing. In doing so, however, the APSC noted that a determination of whether the supplemental information supporting certain nuclear expenditures will be considered in the hearing for the 2017 formula rate plan filing or a separate hearing will be made at a later time. 2017 Formula Rate Plan Filing In July 2017, Entergy Arkansas filed with the APSC its 2017 formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2018 test period to be below the formula rate plan bandwidth. The filing projected a $129.7 million revenue requirement increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . Because the projected revenue increase exceeds the four percent annual revenue constraint for each rate class, however, Entergy Arkansas proposed a $70.9 million revenue requirement increase. Entergy Arkansas requested an order approving its proposed formula rate plan adjustment by December 13, 2017. If a final order is not issued by this date, the proposed formula rate plan adjustment will become effective January 2, 2018, subject to refund. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in September 2016, Entergy Arkansas filed an application seeking a finding from the APSC that Entergy Arkansas’s deployment of advanced metering infrastructure is in the public interest. In June 2017 the APSC staff and Arkansas Attorney General filed direct testimony. The APSC staff generally supported Entergy Arkansas’s AMI deployment conditioned on various recommendations. The Arkansas Attorney General’s consultant primarily recommended denial of Entergy Arkansas’s application but alternatively suggested recommendations in the event the APSC approves Entergy Arkansas’s proposal. Entergy Arkansas filed rebuttal testimony in June 2017, substantially accepting the APSC staff’s recommendations. In August 2017, Entergy Arkansas and the parties to the proceeding filed a joint motion to suspend the procedural schedule pending the filing with the APSC of an agreement in principle on all issues. Filings with the LPSC Retail Rates - Electric 2014 Formula Rate Plan Filing As discussed in the Form 10-K, in September 2015, Entergy Louisiana filed its formula rate plan evaluation report for Entergy Gulf States Louisiana’s and Entergy Louisiana’s 2014 calendar year operations. In June 2017 the LPSC staff and Entergy Louisiana filed an unopposed joint report of proceedings, which was accepted by the LPSC in June 2017, finalizing the results of this proceeding with no changes to rates already implemented. 2015 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. In June 2017 the LPSC staff and Entergy Louisiana filed a joint report of proceedings, which was accepted by the LPSC in June 2017, finalizing the results of the May 2016 evaluation report, interim updates, and corresponding proceedings with no changes to rates already implemented. Also, in November 2016, Entergy Louisiana filed with the LPSC a request to extend the MISO cost recovery mechanism rider provision of its formula rate plan. In March 2017 the LPSC staff submitted direct testimony generally supportive of a one-year extension of the MISO cost recovery mechanism and the intervenor in the proceeding does not oppose an extension for this period of time. In June 2017 an uncontested joint stipulation authorizing a one-year extension of the MISO cost recovery mechanism rider was filed and the LPSC approved the stipulation in July 2017. 2016 Formula Rate Plan Filing In May 2017, Entergy Louisiana filed its formula rate plan evaluation report for its 2016 calendar year operations. The evaluation report reflects an earned return on common equity of 9.84% . As such, no adjustment to base formula rate plan revenue is required. The following adjustments, however, are required under the formula rate plan: The 2016 formula rate plan evaluation report shows a decrease in formula rate plan revenue of approximately $16.9 million , comprised of a decrease in legacy Entergy Louisiana formula rate plan revenue of $3.5 million , a decrease in legacy Entergy Gulf States Louisiana formula rate plan revenue of $9.7 million , and a decrease in incremental formula rate plan revenue of $3.6 million . Additionally, the formula rate plan evaluation report calls for a decrease in the MISO cost recovery revenue requirement of $40.5 million , from the present level of $46.8 million to $6.3 million . Rates reflecting these adjustments will be implemented with the first billing cycle of September 2017, subject to refund, pending the review proceedings. Parties have intervened in the proceedings. No procedural schedule has been established. Waterford 3 Replacement Steam Generator Project See Note 2 to the financial statements in the Form 10-K for discussion of the Waterford 3 replacement steam generator project prudence review proceeding. The refund to customers of approximately $71 million as a result of the settlement approved by the LPSC was made to customers in January 2017. Following a review by the parties, an unopposed joint report of proceedings was filed by the LPSC staff and Entergy Louisiana in May 2017. In May 2017 the LPSC accepted the joint report of proceedings resolving the matter. Union Power Station 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 the decision to deactivate Willow Glen 2 and 4. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three year term permitted by MISO. This matter is pending before an ALJ, with an evidentiary hearing scheduled in August 2017. Retail Rates - Gas 2016 Rate Stabilization Plan Filing In January 2017, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2016. The filing of the evaluation report for test year 2016 reflected an earned return on common equity of 6.37% . As part of the original filing, pursuant to the extraordinary cost provision of the rate stabilization plan, Entergy Louisiana sought to recover approximately $1.5 million in deferred operation and maintenance expenses incurred to restore service and repair damage resulting from flooding and widespread rainfall in southeast Louisiana that occurred in August 2016. Entergy Louisiana requested to recover the prudently incurred August 2016 storm restoration costs over ten years, outside of the rate stabilization plan sharing provisions. As a result, Entergy Louisiana’s filing sought an annual increase in revenue of $1.4 million . Following review of the filing, except for the proposed extraordinary cost recovery, the LPSC staff confirmed Entergy Louisiana’s filing was consistent with the principles and requirements of the rate stabilization plan. The extraordinary cost recovery request associated with the 2016 flood-related deferred operation and maintenance expenses incurred for gas operations was removed from the rate stabilization plan pending LPSC consideration in a separate docket. In April 2017 the LPSC approved a joint report of proceedings and Entergy Louisiana submitted a revised evaluation report reflecting a $1.2 million annual increase in revenue with rates implemented with the first billing cycle of May 2017. In connection with the joint report of proceedings accepted by the LPSC, in May 2017, Entergy Louisiana filed an application to initiate a separate proceeding to recover the deferred operation and maintenance expenses incurred to restore service and repair damage resulting from flooding and widespread rainfall in southeast Louisiana that occurred in August 2016 through the extraordinary cost provision of the gas rate stabilization plan. A procedural schedule has been established, with a hearing in November 2017. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in November 2016, Entergy Louisiana filed an application seeking a finding from the LPSC that Entergy Louisiana’s deployment of advanced electric and gas metering infrastructure is in the public interest. The parties reached an uncontested stipulation permitting implementation of Entergy Louisiana’s proposed AMI system, with modifications to the proposed customer charge. In July 2017 the LPSC approved the stipulation. Filings with the MPSC Formula Rate Plan In March 2017, Entergy Mississippi submitted its formula rate plan 2017 test year filing and 2016 look-back filing showing Entergy Mississippi’s earned return for the historical 2016 calendar year and projected earned return for the 2017 calendar year to be within the formula rate plan bandwidth, resulting in no change in rates. In June 2017, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a stipulation that confirmed that Entergy Mississippi’s earned returns for both the 2016 look-back filing and 2017 test year were within the respective formula rate plan bandwidths. In June 2017 the MPSC approved the stipulation, which resulted in no change in rates. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in November 2016, Entergy Mississippi filed an application seeking a finding from the MPSC that Entergy Mississippi’s deployment of advanced metering infrastructure is in the public interest. In May 2017 the Mississippi Public Utilities Staff and Entergy Mississippi entered into and filed a joint stipulation supporting Entergy Mississippi’s filing, and the MPSC issued an order approving the filing without any material changes, finding that Entergy Mississippi’s deployment of AMI is in the public interest and granting a certificate of public convenience and necessity. The MPSC order also confirmed that Entergy Mississippi shall continue to include in rate base the remaining book value of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Filings with the City Council Retail Rates As discussed in the Form 10-K, in February 2017, Entergy New Orleans filed a proposed implementation plan for the Energy Smart program from April 2017 through March 2020. As part of the proposal, Entergy New Orleans requested that the City Council identify its desired level of funding for the program during this time period and approve a cost recovery mechanism. In April 2017 the City Council approved an implementation plan for the Energy Smart program from April 2017 through December 2019. The City Council directed that the $11.8 million balance reported for Energy Smart funds be used to continue funding the program for Entergy New Orleans’s legacy customers and that the Energy Smart Algiers program continue to be funded through the Algiers fuel adjustment clause, until additional customer funding is required for the legacy customers. The City Council ordered Entergy New Orleans to submit a supplemental and amended implementation plan for program years 8 and 9 of the Energy Smart program (January 2018 through December 2019) in October 2017. Following that filing, the City Council will determine a specific cost recovery mechanism for the program for both legacy and Algiers customers. The City Council will not permit Entergy New Orleans to recover lost contribution to fixed costs for program years 7, 8, or 9 of the Energy Smart program. Internal Restructuring As discussed in the Form 10-K, in July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring that 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 owned by an existing Entergy subsidiary holding company. In May 2017 the City Council adopted a resolution approving the proposed internal restructuring pursuant to an agreement in principle with the City Council advisors and certain intervenors. Pursuant to the agreement in principle, Entergy New Orleans will credit retail customers $10 million in 2017, $1.4 million in the first quarter of the year after the transaction closes, and $117,500 each month in the second year after the transaction closes until such time as new base rates go into effect as a result of the anticipated 2018 base rate case. Entergy New Orleans began crediting retail customers in June 2017. Also pursuant to the agreement in principle, if FERC approval is received prior to December 31, 2018, Entergy New Orleans will provide additional credits to retail customers of $5 million in each of the years 2018, 2019, and 2020. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in October 2016, Entergy New Orleans filed an application seeking a finding from the City Council that Entergy New Orleans’s deployment of advanced electric and gas metering infrastructure is in the public interest. In April 2017, Entergy New Orleans received intervenor testimony that was generally supportive of AMI deployment. The City Council’s advisors filed testimony in May 2017 recommending the adoption of AMI subject to certain modifications, including the denial of Entergy New Orleans’s proposed customer charge as a cost recovery mechanism. In June 2017 the procedural schedule was suspended to allow for settlement discussions. A settlement status conference is scheduled for August 2017. Filings with the PUCT Other Filings In September 2016, Entergy Texas filed with the PUCT a request to amend its transmission cost recovery factor (TCRF) rider. The proposed amended TCRF rider is designed to collect approximately $29.5 million annually from Entergy Texas’s retail customers. This amount includes the approximately $10.5 million annually that Entergy Texas is currently authorized to collect through the TCRF rider. In September 2016 the PUCT suspended the effective date of the tariff change to March 2017. In December 2016, Entergy Texas and the PUCT reached a settlement agreeing to the amended TCRF annual revenue requirement of $29.5 million . The PUCT approved the settlement and issued a final order in March 2017. Entergy Texas implemented the amended TCRF rider beginning with bills covering usage on and after March 20, 2017. In June 2017, Entergy Texas filed an application to amend its distribution cost recovery factor (DCRF) rider by increasing the total collection from $8.65 million to approximately $19 million . In July 2017, Entergy Texas, the PUCT, and the two other parties in the proceeding entered into an unopposed stipulation and settlement agreement resulting in an amended DCRF annual revenue requirement of $18.3 million , with the resulting rates effective for usage no later than October 1, 2017. PUCT action on the stipulation and settlement agreement remains pending. Advanced Metering Infrastructure (AMI) Filing In its most recent regular session, the Texas legislature enacted legislation that extends statutory support for AMI deployment to Entergy Texas and directs that if Entergy Texas elects to deploy AMI, it shall do so as rapidly as practicable. In July 2017, Entergy Texas filed an application seeking an order from the PUCT approving Entergy Texas’s deployment of AMI. Entergy Texas proposed to replace existing meters with advanced meters that enable two-way data communication; design and build a secure and reliable network to support such communications; and implement support systems. AMI is intended to serve as the foundation of Entergy Texas’s modernized power grid. The filing identified a number of quantified and unquantified benefits, with Entergy Texas showing that its AMI deployment is expected to produce nominal net operational cost savings to customers of $33 million . Entergy Texas also sought to continue to include in rate base the remaining book value, approximately $41 million at December 31, 2016, of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Entergy Texas proposed a seven-year depreciable life for the new advanced meters, the three-year deployment of which is expected to begin in 2019. Entergy Texas also proposed a surcharge tariff to recover the reasonable and necessary costs it has and will incur under the deployment plan for the full deployment of advanced meters. Further, Entergy Texas is seeking approval of fees that would be charged to customers who choose to opt out of receiving service through an advanced meter and instead receive electric service with a non-standard meter. Subject to approval by the PUCT, deployment of the communications network is expected to begin in 2018. Entergy Texas expects a decision from the PUCT by December 2017. System Agreement Cost Equalization Proceedings See the Form 10-K for a discussion of the litigation involving the System Agreement at the FERC and in federal courts. Entergy Arkansas Opportunity Sales Proceedings As discussed in the Form 10-K, in June 2009 the LPSC filed a complaint requesting 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 allocated 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 prohibited sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. The LPSC’s complaint challenges sales made beginning in 2002 and requests refunds. In April 2016 the FERC issued orders addressing requests for rehearing filed in July 2012 and an 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 August 2013 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. In May 2016, Entergy Services filed a request for rehearing of the FERC’s April 2016 order addressing the requests for rehearing filed in July 2012. Entergy Services also filed a request for clarification and/or rehearing of the FERC’s April 2016 order addressing the ALJ’s August 2013 initial decision. The APSC and the LPSC also filed requests for rehearing of the FERC’s April 2016 order. The rehearing and clarification requests filed in May 2016 are pending FERC action. Pursuant to the procedural schedule established in the case, Entergy Services re-ran intra-system bills for the ten-year period 2000-2009 to quantify the effects of the FERC's ruling. In November 2016 the LPSC submitted testimony disputing certain aspects of the calculations, and Entergy Services submitted answering testimony in January 2017. In February 2017 the FERC staff filed testimony and Entergy Services filed responsive testimony. In March 2017 the LPSC filed rebuttal testimony. A hearing was held in May 2017. In July 2017, the ALJ issued an initial decision concluding that Entergy Arkansas should pay $86 million plus interest to the other Utility operating companies. The Utility operating companies have the opportunity to challenge the ALJ’s initial decision by filing a brief on exceptions with the FERC. No payments will be made or received by the Utility operating companies until the FERC issues an order reviewing the initial decision and Entergy submits a subsequent filing to comply with that order. The effect of the FERC’s decisions thus far in the case would be that Entergy Arkansas will make payments to some or all of the other Utility operating companies. Because further proceedings will still occur in the case, the amount and recipients of payments by Entergy Arkansas are unknown at this time. Based on testimony previously submitted in the case and its assessment of the April 2016 FERC orders, in the first quarter 2016, Entergy Arkansas recorded a liability of $87 million , which includes interest, for its estimated increased costs and payment to the other Utility operating companies. This estimate is subject to change depending on how the FERC resolves the issues that are still outstanding in the case, including its review of the July 2017 initial decision. 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. Entergy Arkansas, therefore, recorded a regulatory asset in the first quarter 2016 of approximately $75 million , which represents its estimate of the retail portion of the costs. Complaint Against System Energy In January 2017 the APSC and MPSC filed a complaint with the FERC against System Energy. The complaint seeks a reduction in the return on equity component of the Unit Power Sales Agreement pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. Entergy Arkansas also sells some of its Grand Gulf capacity and energy to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans under separate agreements. The current return on equity under the Unit Power Sales Agreement is 10.94% . The complaint alleges that the return on equity is unjust and unreasonable because current capital market and other considerations indicate that it is excessive. The complaint requests the FERC to institute proceedings to investigate the return on equity and establish a lower return on equity, and also requests that the FERC establish January 23, 2017 as a refund effective date. The complaint includes return on equity analysis that purports to establish that the range of reasonable return on equity for System Energy is between 8.37% and 8.67% . System Energy answered the complaint in February 2017 and disputes that a return on equity of 8.37% to 8.67% is just and reasonable. The LPSC and the City Council intervened in the proceeding expressing support for the complaint. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Action by the FERC is pending. Unit Power Sales Agreement In August 2017, System Energy submitted to the FERC proposed amendments to the Unit Power Sales Agreement pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. The filing proposes limited amendments to the Unit Power Sales Agreement to adopt (1) updated rates for use in calculating Grand Gulf plant depreciation and amortization expenses and (2) updated nuclear decommissioning cost annual revenue requirements, both of which are recovered through the Unit Power Sales Agreement rate formula. The proposed amendments would result in lower charges to the Utility operating companies that buy capacity and energy from System Energy under the Unit Power Sales Agreement. The proposed changes are based on updated depreciation and nuclear decommissioning studies that take into account the renewal of Grand Gulf’s operating license for a term through November 1, 2044. System Energy requested that the FERC accept the amendments effective October 1, 2017. Action by the FERC is pending.
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 Energy Cost Recovery Rider In March 2017, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01164 per kWh to $0.01547 per kWh. The APSC staff filed testimony in March 2017 recommending that the redetermined rate should be implemented with the first billing cycle of April 2017 under the normal operation of the tariff. Accordingly, the redetermined rate went into effect on March 31, 2017 pursuant to the tariff. In July 2017 the Arkansas Attorney General requested additional information to support certain of the costs included in Entergy Arkansas’s 2017 energy cost rate redetermination. Entergy Louisiana As discussed in the Form 10-K, in June 2016 the LPSC staff provided notice of audits of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. Discovery commenced in March 2017. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi attorney general filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power. The defendants have denied the allegations. In June 2017 the District Court issued a case management order setting a trial date in November 2018. Discovery is currently in progress. Entergy Texas As discussed in the Form 10-K, 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. In December 2016, Entergy Texas entered into a stipulation and settlement agreement resulting in a $6 million disallowance not associated with any particular issue raised and a refund of the over-recovery balance of $21 million as of November 30, 2016, to most customers beginning April 2017 through June 2017. The fuel reconciliation settlement was approved by the PUCT in March 2017 and the refunds were made. In June 2017, Entergy Texas filed an application for a fuel refund of approximately $30.7 million for the months of December 2016 through April 2017. For most customers, the refunds will flow through bills for the months of July 2017 through September 2017. Also in June 2017, the PUCT’s administrative law judge approved the refund on an interim basis. A final decision in this matter remains pending. 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 2016 Formula Rate Plan Filing As discussed in the Form 10-K, Entergy Arkansas is required to make a supplemental filing supporting the recovery of certain nuclear costs. In April 2017, Entergy Arkansas filed a motion consented to by all parties requesting that it be permitted to submit its supplemental filing in conjunction with its 2017 formula rate plan filing, which was subsequently made in July 2017 and is discussed below. In May 2017 the APSC approved the joint motion and proposal to review Entergy Arkansas’s supplemental filing on a concurrent schedule with the 2017 formula rate plan filing. In doing so, however, the APSC noted that a determination of whether the supplemental information supporting certain nuclear expenditures will be considered in the hearing for the 2017 formula rate plan filing or a separate hearing will be made at a later time. 2017 Formula Rate Plan Filing In July 2017, Entergy Arkansas filed with the APSC its 2017 formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2018 test period to be below the formula rate plan bandwidth. The filing projected a $129.7 million revenue requirement increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . Because the projected revenue increase exceeds the four percent annual revenue constraint for each rate class, however, Entergy Arkansas proposed a $70.9 million revenue requirement increase. Entergy Arkansas requested an order approving its proposed formula rate plan adjustment by December 13, 2017. If a final order is not issued by this date, the proposed formula rate plan adjustment will become effective January 2, 2018, subject to refund. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in September 2016, Entergy Arkansas filed an application seeking a finding from the APSC that Entergy Arkansas’s deployment of advanced metering infrastructure is in the public interest. In June 2017 the APSC staff and Arkansas Attorney General filed direct testimony. The APSC staff generally supported Entergy Arkansas’s AMI deployment conditioned on various recommendations. The Arkansas Attorney General’s consultant primarily recommended denial of Entergy Arkansas’s application but alternatively suggested recommendations in the event the APSC approves Entergy Arkansas’s proposal. Entergy Arkansas filed rebuttal testimony in June 2017, substantially accepting the APSC staff’s recommendations. In August 2017, Entergy Arkansas and the parties to the proceeding filed a joint motion to suspend the procedural schedule pending the filing with the APSC of an agreement in principle on all issues. Filings with the LPSC Retail Rates - Electric 2014 Formula Rate Plan Filing As discussed in the Form 10-K, in September 2015, Entergy Louisiana filed its formula rate plan evaluation report for Entergy Gulf States Louisiana’s and Entergy Louisiana’s 2014 calendar year operations. In June 2017 the LPSC staff and Entergy Louisiana filed an unopposed joint report of proceedings, which was accepted by the LPSC in June 2017, finalizing the results of this proceeding with no changes to rates already implemented. 2015 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. In June 2017 the LPSC staff and Entergy Louisiana filed a joint report of proceedings, which was accepted by the LPSC in June 2017, finalizing the results of the May 2016 evaluation report, interim updates, and corresponding proceedings with no changes to rates already implemented. Also, in November 2016, Entergy Louisiana filed with the LPSC a request to extend the MISO cost recovery mechanism rider provision of its formula rate plan. In March 2017 the LPSC staff submitted direct testimony generally supportive of a one-year extension of the MISO cost recovery mechanism and the intervenor in the proceeding does not oppose an extension for this period of time. In June 2017 an uncontested joint stipulation authorizing a one-year extension of the MISO cost recovery mechanism rider was filed and the LPSC approved the stipulation in July 2017. 2016 Formula Rate Plan Filing In May 2017, Entergy Louisiana filed its formula rate plan evaluation report for its 2016 calendar year operations. The evaluation report reflects an earned return on common equity of 9.84% . As such, no adjustment to base formula rate plan revenue is required. The following adjustments, however, are required under the formula rate plan: The 2016 formula rate plan evaluation report shows a decrease in formula rate plan revenue of approximately $16.9 million , comprised of a decrease in legacy Entergy Louisiana formula rate plan revenue of $3.5 million , a decrease in legacy Entergy Gulf States Louisiana formula rate plan revenue of $9.7 million , and a decrease in incremental formula rate plan revenue of $3.6 million . Additionally, the formula rate plan evaluation report calls for a decrease in the MISO cost recovery revenue requirement of $40.5 million , from the present level of $46.8 million to $6.3 million . Rates reflecting these adjustments will be implemented with the first billing cycle of September 2017, subject to refund, pending the review proceedings. Parties have intervened in the proceedings. No procedural schedule has been established. Waterford 3 Replacement Steam Generator Project See Note 2 to the financial statements in the Form 10-K for discussion of the Waterford 3 replacement steam generator project prudence review proceeding. The refund to customers of approximately $71 million as a result of the settlement approved by the LPSC was made to customers in January 2017. Following a review by the parties, an unopposed joint report of proceedings was filed by the LPSC staff and Entergy Louisiana in May 2017. In May 2017 the LPSC accepted the joint report of proceedings resolving the matter. Union Power Station 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 the decision to deactivate Willow Glen 2 and 4. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three year term permitted by MISO. This matter is pending before an ALJ, with an evidentiary hearing scheduled in August 2017. Retail Rates - Gas 2016 Rate Stabilization Plan Filing In January 2017, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2016. The filing of the evaluation report for test year 2016 reflected an earned return on common equity of 6.37% . As part of the original filing, pursuant to the extraordinary cost provision of the rate stabilization plan, Entergy Louisiana sought to recover approximately $1.5 million in deferred operation and maintenance expenses incurred to restore service and repair damage resulting from flooding and widespread rainfall in southeast Louisiana that occurred in August 2016. Entergy Louisiana requested to recover the prudently incurred August 2016 storm restoration costs over ten years, outside of the rate stabilization plan sharing provisions. As a result, Entergy Louisiana’s filing sought an annual increase in revenue of $1.4 million . Following review of the filing, except for the proposed extraordinary cost recovery, the LPSC staff confirmed Entergy Louisiana’s filing was consistent with the principles and requirements of the rate stabilization plan. The extraordinary cost recovery request associated with the 2016 flood-related deferred operation and maintenance expenses incurred for gas operations was removed from the rate stabilization plan pending LPSC consideration in a separate docket. In April 2017 the LPSC approved a joint report of proceedings and Entergy Louisiana submitted a revised evaluation report reflecting a $1.2 million annual increase in revenue with rates implemented with the first billing cycle of May 2017. In connection with the joint report of proceedings accepted by the LPSC, in May 2017, Entergy Louisiana filed an application to initiate a separate proceeding to recover the deferred operation and maintenance expenses incurred to restore service and repair damage resulting from flooding and widespread rainfall in southeast Louisiana that occurred in August 2016 through the extraordinary cost provision of the gas rate stabilization plan. A procedural schedule has been established, with a hearing in November 2017. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in November 2016, Entergy Louisiana filed an application seeking a finding from the LPSC that Entergy Louisiana’s deployment of advanced electric and gas metering infrastructure is in the public interest. The parties reached an uncontested stipulation permitting implementation of Entergy Louisiana’s proposed AMI system, with modifications to the proposed customer charge. In July 2017 the LPSC approved the stipulation. Filings with the MPSC Formula Rate Plan In March 2017, Entergy Mississippi submitted its formula rate plan 2017 test year filing and 2016 look-back filing showing Entergy Mississippi’s earned return for the historical 2016 calendar year and projected earned return for the 2017 calendar year to be within the formula rate plan bandwidth, resulting in no change in rates. In June 2017, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a stipulation that confirmed that Entergy Mississippi’s earned returns for both the 2016 look-back filing and 2017 test year were within the respective formula rate plan bandwidths. In June 2017 the MPSC approved the stipulation, which resulted in no change in rates. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in November 2016, Entergy Mississippi filed an application seeking a finding from the MPSC that Entergy Mississippi’s deployment of advanced metering infrastructure is in the public interest. In May 2017 the Mississippi Public Utilities Staff and Entergy Mississippi entered into and filed a joint stipulation supporting Entergy Mississippi’s filing, and the MPSC issued an order approving the filing without any material changes, finding that Entergy Mississippi’s deployment of AMI is in the public interest and granting a certificate of public convenience and necessity. The MPSC order also confirmed that Entergy Mississippi shall continue to include in rate base the remaining book value of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Filings with the City Council Retail Rates As discussed in the Form 10-K, in February 2017, Entergy New Orleans filed a proposed implementation plan for the Energy Smart program from April 2017 through March 2020. As part of the proposal, Entergy New Orleans requested that the City Council identify its desired level of funding for the program during this time period and approve a cost recovery mechanism. In April 2017 the City Council approved an implementation plan for the Energy Smart program from April 2017 through December 2019. The City Council directed that the $11.8 million balance reported for Energy Smart funds be used to continue funding the program for Entergy New Orleans’s legacy customers and that the Energy Smart Algiers program continue to be funded through the Algiers fuel adjustment clause, until additional customer funding is required for the legacy customers. The City Council ordered Entergy New Orleans to submit a supplemental and amended implementation plan for program years 8 and 9 of the Energy Smart program (January 2018 through December 2019) in October 2017. Following that filing, the City Council will determine a specific cost recovery mechanism for the program for both legacy and Algiers customers. The City Council will not permit Entergy New Orleans to recover lost contribution to fixed costs for program years 7, 8, or 9 of the Energy Smart program. Internal Restructuring As discussed in the Form 10-K, in July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring that 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 owned by an existing Entergy subsidiary holding company. In May 2017 the City Council adopted a resolution approving the proposed internal restructuring pursuant to an agreement in principle with the City Council advisors and certain intervenors. Pursuant to the agreement in principle, Entergy New Orleans will credit retail customers $10 million in 2017, $1.4 million in the first quarter of the year after the transaction closes, and $117,500 each month in the second year after the transaction closes until such time as new base rates go into effect as a result of the anticipated 2018 base rate case. Entergy New Orleans began crediting retail customers in June 2017. Also pursuant to the agreement in principle, if FERC approval is received prior to December 31, 2018, Entergy New Orleans will provide additional credits to retail customers of $5 million in each of the years 2018, 2019, and 2020. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in October 2016, Entergy New Orleans filed an application seeking a finding from the City Council that Entergy New Orleans’s deployment of advanced electric and gas metering infrastructure is in the public interest. In April 2017, Entergy New Orleans received intervenor testimony that was generally supportive of AMI deployment. The City Council’s advisors filed testimony in May 2017 recommending the adoption of AMI subject to certain modifications, including the denial of Entergy New Orleans’s proposed customer charge as a cost recovery mechanism. In June 2017 the procedural schedule was suspended to allow for settlement discussions. A settlement status conference is scheduled for August 2017. Filings with the PUCT Other Filings In September 2016, Entergy Texas filed with the PUCT a request to amend its transmission cost recovery factor (TCRF) rider. The proposed amended TCRF rider is designed to collect approximately $29.5 million annually from Entergy Texas’s retail customers. This amount includes the approximately $10.5 million annually that Entergy Texas is currently authorized to collect through the TCRF rider. In September 2016 the PUCT suspended the effective date of the tariff change to March 2017. In December 2016, Entergy Texas and the PUCT reached a settlement agreeing to the amended TCRF annual revenue requirement of $29.5 million . The PUCT approved the settlement and issued a final order in March 2017. Entergy Texas implemented the amended TCRF rider beginning with bills covering usage on and after March 20, 2017. In June 2017, Entergy Texas filed an application to amend its distribution cost recovery factor (DCRF) rider by increasing the total collection from $8.65 million to approximately $19 million . In July 2017, Entergy Texas, the PUCT, and the two other parties in the proceeding entered into an unopposed stipulation and settlement agreement resulting in an amended DCRF annual revenue requirement of $18.3 million , with the resulting rates effective for usage no later than October 1, 2017. PUCT action on the stipulation and settlement agreement remains pending. Advanced Metering Infrastructure (AMI) Filing In its most recent regular session, the Texas legislature enacted legislation that extends statutory support for AMI deployment to Entergy Texas and directs that if Entergy Texas elects to deploy AMI, it shall do so as rapidly as practicable. In July 2017, Entergy Texas filed an application seeking an order from the PUCT approving Entergy Texas’s deployment of AMI. Entergy Texas proposed to replace existing meters with advanced meters that enable two-way data communication; design and build a secure and reliable network to support such communications; and implement support systems. AMI is intended to serve as the foundation of Entergy Texas’s modernized power grid. The filing identified a number of quantified and unquantified benefits, with Entergy Texas showing that its AMI deployment is expected to produce nominal net operational cost savings to customers of $33 million . Entergy Texas also sought to continue to include in rate base the remaining book value, approximately $41 million at December 31, 2016, of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Entergy Texas proposed a seven-year depreciable life for the new advanced meters, the three-year deployment of which is expected to begin in 2019. Entergy Texas also proposed a surcharge tariff to recover the reasonable and necessary costs it has and will incur under the deployment plan for the full deployment of advanced meters. Further, Entergy Texas is seeking approval of fees that would be charged to customers who choose to opt out of receiving service through an advanced meter and instead receive electric service with a non-standard meter. Subject to approval by the PUCT, deployment of the communications network is expected to begin in 2018. Entergy Texas expects a decision from the PUCT by December 2017. System Agreement Cost Equalization Proceedings See the Form 10-K for a discussion of the litigation involving the System Agreement at the FERC and in federal courts. Entergy Arkansas Opportunity Sales Proceedings As discussed in the Form 10-K, in June 2009 the LPSC filed a complaint requesting 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 allocated 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 prohibited sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. The LPSC’s complaint challenges sales made beginning in 2002 and requests refunds. In April 2016 the FERC issued orders addressing requests for rehearing filed in July 2012 and an 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 August 2013 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. In May 2016, Entergy Services filed a request for rehearing of the FERC’s April 2016 order addressing the requests for rehearing filed in July 2012. Entergy Services also filed a request for clarification and/or rehearing of the FERC’s April 2016 order addressing the ALJ’s August 2013 initial decision. The APSC and the LPSC also filed requests for rehearing of the FERC’s April 2016 order. The rehearing and clarification requests filed in May 2016 are pending FERC action. Pursuant to the procedural schedule established in the case, Entergy Services re-ran intra-system bills for the ten-year period 2000-2009 to quantify the effects of the FERC's ruling. In November 2016 the LPSC submitted testimony disputing certain aspects of the calculations, and Entergy Services submitted answering testimony in January 2017. In February 2017 the FERC staff filed testimony and Entergy Services filed responsive testimony. In March 2017 the LPSC filed rebuttal testimony. A hearing was held in May 2017. In July 2017, the ALJ issued an initial decision concluding that Entergy Arkansas should pay $86 million plus interest to the other Utility operating companies. The Utility operating companies have the opportunity to challenge the ALJ’s initial decision by filing a brief on exceptions with the FERC. No payments will be made or received by the Utility operating companies until the FERC issues an order reviewing the initial decision and Entergy submits a subsequent filing to comply with that order. The effect of the FERC’s decisions thus far in the case would be that Entergy Arkansas will make payments to some or all of the other Utility operating companies. Because further proceedings will still occur in the case, the amount and recipients of payments by Entergy Arkansas are unknown at this time. Based on testimony previously submitted in the case and its assessment of the April 2016 FERC orders, in the first quarter 2016, Entergy Arkansas recorded a liability of $87 million , which includes interest, for its estimated increased costs and payment to the other Utility operating companies. This estimate is subject to change depending on how the FERC resolves the issues that are still outstanding in the case, including its review of the July 2017 initial decision. 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. Entergy Arkansas, therefore, recorded a regulatory asset in the first quarter 2016 of approximately $75 million , which represents its estimate of the retail portion of the costs. Complaint Against System Energy In January 2017 the APSC and MPSC filed a complaint with the FERC against System Energy. The complaint seeks a reduction in the return on equity component of the Unit Power Sales Agreement pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. Entergy Arkansas also sells some of its Grand Gulf capacity and energy to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans under separate agreements. The current return on equity under the Unit Power Sales Agreement is 10.94% . The complaint alleges that the return on equity is unjust and unreasonable because current capital market and other considerations indicate that it is excessive. The complaint requests the FERC to institute proceedings to investigate the return on equity and establish a lower return on equity, and also requests that the FERC establish January 23, 2017 as a refund effective date. The complaint includes return on equity analysis that purports to establish that the range of reasonable return on equity for System Energy is between 8.37% and 8.67% . System Energy answered the complaint in February 2017 and disputes that a return on equity of 8.37% to 8.67% is just and reasonable. The LPSC and the City Council intervened in the proceeding expressing support for the complaint. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Action by the FERC is pending. Unit Power Sales Agreement In August 2017, System Energy submitted to the FERC proposed amendments to the Unit Power Sales Agreement pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. The filing proposes limited amendments to the Unit Power Sales Agreement to adopt (1) updated rates for use in calculating Grand Gulf plant depreciation and amortization expenses and (2) updated nuclear decommissioning cost annual revenue requirements, both of which are recovered through the Unit Power Sales Agreement rate formula. The proposed amendments would result in lower charges to the Utility operating companies that buy capacity and energy from System Energy under the Unit Power Sales Agreement. The proposed changes are based on updated depreciation and nuclear decommissioning studies that take into account the renewal of Grand Gulf’s operating license for a term through November 1, 2044. System Energy requested that the FERC accept the amendments effective October 1, 2017. Action by the FERC is pending.
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 Energy Cost Recovery Rider In March 2017, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01164 per kWh to $0.01547 per kWh. The APSC staff filed testimony in March 2017 recommending that the redetermined rate should be implemented with the first billing cycle of April 2017 under the normal operation of the tariff. Accordingly, the redetermined rate went into effect on March 31, 2017 pursuant to the tariff. In July 2017 the Arkansas Attorney General requested additional information to support certain of the costs included in Entergy Arkansas’s 2017 energy cost rate redetermination. Entergy Louisiana As discussed in the Form 10-K, in June 2016 the LPSC staff provided notice of audits of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. Discovery commenced in March 2017. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi attorney general filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power. The defendants have denied the allegations. In June 2017 the District Court issued a case management order setting a trial date in November 2018. Discovery is currently in progress. Entergy Texas As discussed in the Form 10-K, 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. In December 2016, Entergy Texas entered into a stipulation and settlement agreement resulting in a $6 million disallowance not associated with any particular issue raised and a refund of the over-recovery balance of $21 million as of November 30, 2016, to most customers beginning April 2017 through June 2017. The fuel reconciliation settlement was approved by the PUCT in March 2017 and the refunds were made. In June 2017, Entergy Texas filed an application for a fuel refund of approximately $30.7 million for the months of December 2016 through April 2017. For most customers, the refunds will flow through bills for the months of July 2017 through September 2017. Also in June 2017, the PUCT’s administrative law judge approved the refund on an interim basis. A final decision in this matter remains pending. 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 2016 Formula Rate Plan Filing As discussed in the Form 10-K, Entergy Arkansas is required to make a supplemental filing supporting the recovery of certain nuclear costs. In April 2017, Entergy Arkansas filed a motion consented to by all parties requesting that it be permitted to submit its supplemental filing in conjunction with its 2017 formula rate plan filing, which was subsequently made in July 2017 and is discussed below. In May 2017 the APSC approved the joint motion and proposal to review Entergy Arkansas’s supplemental filing on a concurrent schedule with the 2017 formula rate plan filing. In doing so, however, the APSC noted that a determination of whether the supplemental information supporting certain nuclear expenditures will be considered in the hearing for the 2017 formula rate plan filing or a separate hearing will be made at a later time. 2017 Formula Rate Plan Filing In July 2017, Entergy Arkansas filed with the APSC its 2017 formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2018 test period to be below the formula rate plan bandwidth. The filing projected a $129.7 million revenue requirement increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . Because the projected revenue increase exceeds the four percent annual revenue constraint for each rate class, however, Entergy Arkansas proposed a $70.9 million revenue requirement increase. Entergy Arkansas requested an order approving its proposed formula rate plan adjustment by December 13, 2017. If a final order is not issued by this date, the proposed formula rate plan adjustment will become effective January 2, 2018, subject to refund. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in September 2016, Entergy Arkansas filed an application seeking a finding from the APSC that Entergy Arkansas’s deployment of advanced metering infrastructure is in the public interest. In June 2017 the APSC staff and Arkansas Attorney General filed direct testimony. The APSC staff generally supported Entergy Arkansas’s AMI deployment conditioned on various recommendations. The Arkansas Attorney General’s consultant primarily recommended denial of Entergy Arkansas’s application but alternatively suggested recommendations in the event the APSC approves Entergy Arkansas’s proposal. Entergy Arkansas filed rebuttal testimony in June 2017, substantially accepting the APSC staff’s recommendations. In August 2017, Entergy Arkansas and the parties to the proceeding filed a joint motion to suspend the procedural schedule pending the filing with the APSC of an agreement in principle on all issues. Filings with the LPSC Retail Rates - Electric 2014 Formula Rate Plan Filing As discussed in the Form 10-K, in September 2015, Entergy Louisiana filed its formula rate plan evaluation report for Entergy Gulf States Louisiana’s and Entergy Louisiana’s 2014 calendar year operations. In June 2017 the LPSC staff and Entergy Louisiana filed an unopposed joint report of proceedings, which was accepted by the LPSC in June 2017, finalizing the results of this proceeding with no changes to rates already implemented. 2015 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. In June 2017 the LPSC staff and Entergy Louisiana filed a joint report of proceedings, which was accepted by the LPSC in June 2017, finalizing the results of the May 2016 evaluation report, interim updates, and corresponding proceedings with no changes to rates already implemented. Also, in November 2016, Entergy Louisiana filed with the LPSC a request to extend the MISO cost recovery mechanism rider provision of its formula rate plan. In March 2017 the LPSC staff submitted direct testimony generally supportive of a one-year extension of the MISO cost recovery mechanism and the intervenor in the proceeding does not oppose an extension for this period of time. In June 2017 an uncontested joint stipulation authorizing a one-year extension of the MISO cost recovery mechanism rider was filed and the LPSC approved the stipulation in July 2017. 2016 Formula Rate Plan Filing In May 2017, Entergy Louisiana filed its formula rate plan evaluation report for its 2016 calendar year operations. The evaluation report reflects an earned return on common equity of 9.84% . As such, no adjustment to base formula rate plan revenue is required. The following adjustments, however, are required under the formula rate plan: The 2016 formula rate plan evaluation report shows a decrease in formula rate plan revenue of approximately $16.9 million , comprised of a decrease in legacy Entergy Louisiana formula rate plan revenue of $3.5 million , a decrease in legacy Entergy Gulf States Louisiana formula rate plan revenue of $9.7 million , and a decrease in incremental formula rate plan revenue of $3.6 million . Additionally, the formula rate plan evaluation report calls for a decrease in the MISO cost recovery revenue requirement of $40.5 million , from the present level of $46.8 million to $6.3 million . Rates reflecting these adjustments will be implemented with the first billing cycle of September 2017, subject to refund, pending the review proceedings. Parties have intervened in the proceedings. No procedural schedule has been established. Waterford 3 Replacement Steam Generator Project See Note 2 to the financial statements in the Form 10-K for discussion of the Waterford 3 replacement steam generator project prudence review proceeding. The refund to customers of approximately $71 million as a result of the settlement approved by the LPSC was made to customers in January 2017. Following a review by the parties, an unopposed joint report of proceedings was filed by the LPSC staff and Entergy Louisiana in May 2017. In May 2017 the LPSC accepted the joint report of proceedings resolving the matter. Union Power Station 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 the decision to deactivate Willow Glen 2 and 4. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three year term permitted by MISO. This matter is pending before an ALJ, with an evidentiary hearing scheduled in August 2017. Retail Rates - Gas 2016 Rate Stabilization Plan Filing In January 2017, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2016. The filing of the evaluation report for test year 2016 reflected an earned return on common equity of 6.37% . As part of the original filing, pursuant to the extraordinary cost provision of the rate stabilization plan, Entergy Louisiana sought to recover approximately $1.5 million in deferred operation and maintenance expenses incurred to restore service and repair damage resulting from flooding and widespread rainfall in southeast Louisiana that occurred in August 2016. Entergy Louisiana requested to recover the prudently incurred August 2016 storm restoration costs over ten years, outside of the rate stabilization plan sharing provisions. As a result, Entergy Louisiana’s filing sought an annual increase in revenue of $1.4 million . Following review of the filing, except for the proposed extraordinary cost recovery, the LPSC staff confirmed Entergy Louisiana’s filing was consistent with the principles and requirements of the rate stabilization plan. The extraordinary cost recovery request associated with the 2016 flood-related deferred operation and maintenance expenses incurred for gas operations was removed from the rate stabilization plan pending LPSC consideration in a separate docket. In April 2017 the LPSC approved a joint report of proceedings and Entergy Louisiana submitted a revised evaluation report reflecting a $1.2 million annual increase in revenue with rates implemented with the first billing cycle of May 2017. In connection with the joint report of proceedings accepted by the LPSC, in May 2017, Entergy Louisiana filed an application to initiate a separate proceeding to recover the deferred operation and maintenance expenses incurred to restore service and repair damage resulting from flooding and widespread rainfall in southeast Louisiana that occurred in August 2016 through the extraordinary cost provision of the gas rate stabilization plan. A procedural schedule has been established, with a hearing in November 2017. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in November 2016, Entergy Louisiana filed an application seeking a finding from the LPSC that Entergy Louisiana’s deployment of advanced electric and gas metering infrastructure is in the public interest. The parties reached an uncontested stipulation permitting implementation of Entergy Louisiana’s proposed AMI system, with modifications to the proposed customer charge. In July 2017 the LPSC approved the stipulation. Filings with the MPSC Formula Rate Plan In March 2017, Entergy Mississippi submitted its formula rate plan 2017 test year filing and 2016 look-back filing showing Entergy Mississippi’s earned return for the historical 2016 calendar year and projected earned return for the 2017 calendar year to be within the formula rate plan bandwidth, resulting in no change in rates. In June 2017, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a stipulation that confirmed that Entergy Mississippi’s earned returns for both the 2016 look-back filing and 2017 test year were within the respective formula rate plan bandwidths. In June 2017 the MPSC approved the stipulation, which resulted in no change in rates. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in November 2016, Entergy Mississippi filed an application seeking a finding from the MPSC that Entergy Mississippi’s deployment of advanced metering infrastructure is in the public interest. In May 2017 the Mississippi Public Utilities Staff and Entergy Mississippi entered into and filed a joint stipulation supporting Entergy Mississippi’s filing, and the MPSC issued an order approving the filing without any material changes, finding that Entergy Mississippi’s deployment of AMI is in the public interest and granting a certificate of public convenience and necessity. The MPSC order also confirmed that Entergy Mississippi shall continue to include in rate base the remaining book value of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Filings with the City Council Retail Rates As discussed in the Form 10-K, in February 2017, Entergy New Orleans filed a proposed implementation plan for the Energy Smart program from April 2017 through March 2020. As part of the proposal, Entergy New Orleans requested that the City Council identify its desired level of funding for the program during this time period and approve a cost recovery mechanism. In April 2017 the City Council approved an implementation plan for the Energy Smart program from April 2017 through December 2019. The City Council directed that the $11.8 million balance reported for Energy Smart funds be used to continue funding the program for Entergy New Orleans’s legacy customers and that the Energy Smart Algiers program continue to be funded through the Algiers fuel adjustment clause, until additional customer funding is required for the legacy customers. The City Council ordered Entergy New Orleans to submit a supplemental and amended implementation plan for program years 8 and 9 of the Energy Smart program (January 2018 through December 2019) in October 2017. Following that filing, the City Council will determine a specific cost recovery mechanism for the program for both legacy and Algiers customers. The City Council will not permit Entergy New Orleans to recover lost contribution to fixed costs for program years 7, 8, or 9 of the Energy Smart program. Internal Restructuring As discussed in the Form 10-K, in July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring that 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 owned by an existing Entergy subsidiary holding company. In May 2017 the City Council adopted a resolution approving the proposed internal restructuring pursuant to an agreement in principle with the City Council advisors and certain intervenors. Pursuant to the agreement in principle, Entergy New Orleans will credit retail customers $10 million in 2017, $1.4 million in the first quarter of the year after the transaction closes, and $117,500 each month in the second year after the transaction closes until such time as new base rates go into effect as a result of the anticipated 2018 base rate case. Entergy New Orleans began crediting retail customers in June 2017. Also pursuant to the agreement in principle, if FERC approval is received prior to December 31, 2018, Entergy New Orleans will provide additional credits to retail customers of $5 million in each of the years 2018, 2019, and 2020. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in October 2016, Entergy New Orleans filed an application seeking a finding from the City Council that Entergy New Orleans’s deployment of advanced electric and gas metering infrastructure is in the public interest. In April 2017, Entergy New Orleans received intervenor testimony that was generally supportive of AMI deployment. The City Council’s advisors filed testimony in May 2017 recommending the adoption of AMI subject to certain modifications, including the denial of Entergy New Orleans’s proposed customer charge as a cost recovery mechanism. In June 2017 the procedural schedule was suspended to allow for settlement discussions. A settlement status conference is scheduled for August 2017. Filings with the PUCT Other Filings In September 2016, Entergy Texas filed with the PUCT a request to amend its transmission cost recovery factor (TCRF) rider. The proposed amended TCRF rider is designed to collect approximately $29.5 million annually from Entergy Texas’s retail customers. This amount includes the approximately $10.5 million annually that Entergy Texas is currently authorized to collect through the TCRF rider. In September 2016 the PUCT suspended the effective date of the tariff change to March 2017. In December 2016, Entergy Texas and the PUCT reached a settlement agreeing to the amended TCRF annual revenue requirement of $29.5 million . The PUCT approved the settlement and issued a final order in March 2017. Entergy Texas implemented the amended TCRF rider beginning with bills covering usage on and after March 20, 2017. In June 2017, Entergy Texas filed an application to amend its distribution cost recovery factor (DCRF) rider by increasing the total collection from $8.65 million to approximately $19 million . In July 2017, Entergy Texas, the PUCT, and the two other parties in the proceeding entered into an unopposed stipulation and settlement agreement resulting in an amended DCRF annual revenue requirement of $18.3 million , with the resulting rates effective for usage no later than October 1, 2017. PUCT action on the stipulation and settlement agreement remains pending. Advanced Metering Infrastructure (AMI) Filing In its most recent regular session, the Texas legislature enacted legislation that extends statutory support for AMI deployment to Entergy Texas and directs that if Entergy Texas elects to deploy AMI, it shall do so as rapidly as practicable. In July 2017, Entergy Texas filed an application seeking an order from the PUCT approving Entergy Texas’s deployment of AMI. Entergy Texas proposed to replace existing meters with advanced meters that enable two-way data communication; design and build a secure and reliable network to support such communications; and implement support systems. AMI is intended to serve as the foundation of Entergy Texas’s modernized power grid. The filing identified a number of quantified and unquantified benefits, with Entergy Texas showing that its AMI deployment is expected to produce nominal net operational cost savings to customers of $33 million . Entergy Texas also sought to continue to include in rate base the remaining book value, approximately $41 million at December 31, 2016, of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Entergy Texas proposed a seven-year depreciable life for the new advanced meters, the three-year deployment of which is expected to begin in 2019. Entergy Texas also proposed a surcharge tariff to recover the reasonable and necessary costs it has and will incur under the deployment plan for the full deployment of advanced meters. Further, Entergy Texas is seeking approval of fees that would be charged to customers who choose to opt out of receiving service through an advanced meter and instead receive electric service with a non-standard meter. Subject to approval by the PUCT, deployment of the communications network is expected to begin in 2018. Entergy Texas expects a decision from the PUCT by December 2017. System Agreement Cost Equalization Proceedings See the Form 10-K for a discussion of the litigation involving the System Agreement at the FERC and in federal courts. Entergy Arkansas Opportunity Sales Proceedings As discussed in the Form 10-K, in June 2009 the LPSC filed a complaint requesting 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 allocated 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 prohibited sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. The LPSC’s complaint challenges sales made beginning in 2002 and requests refunds. In April 2016 the FERC issued orders addressing requests for rehearing filed in July 2012 and an 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 August 2013 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. In May 2016, Entergy Services filed a request for rehearing of the FERC’s April 2016 order addressing the requests for rehearing filed in July 2012. Entergy Services also filed a request for clarification and/or rehearing of the FERC’s April 2016 order addressing the ALJ’s August 2013 initial decision. The APSC and the LPSC also filed requests for rehearing of the FERC’s April 2016 order. The rehearing and clarification requests filed in May 2016 are pending FERC action. Pursuant to the procedural schedule established in the case, Entergy Services re-ran intra-system bills for the ten-year period 2000-2009 to quantify the effects of the FERC's ruling. In November 2016 the LPSC submitted testimony disputing certain aspects of the calculations, and Entergy Services submitted answering testimony in January 2017. In February 2017 the FERC staff filed testimony and Entergy Services filed responsive testimony. In March 2017 the LPSC filed rebuttal testimony. A hearing was held in May 2017. In July 2017, the ALJ issued an initial decision concluding that Entergy Arkansas should pay $86 million plus interest to the other Utility operating companies. The Utility operating companies have the opportunity to challenge the ALJ’s initial decision by filing a brief on exceptions with the FERC. No payments will be made or received by the Utility operating companies until the FERC issues an order reviewing the initial decision and Entergy submits a subsequent filing to comply with that order. The effect of the FERC’s decisions thus far in the case would be that Entergy Arkansas will make payments to some or all of the other Utility operating companies. Because further proceedings will still occur in the case, the amount and recipients of payments by Entergy Arkansas are unknown at this time. Based on testimony previously submitted in the case and its assessment of the April 2016 FERC orders, in the first quarter 2016, Entergy Arkansas recorded a liability of $87 million , which includes interest, for its estimated increased costs and payment to the other Utility operating companies. This estimate is subject to change depending on how the FERC resolves the issues that are still outstanding in the case, including its review of the July 2017 initial decision. 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. Entergy Arkansas, therefore, recorded a regulatory asset in the first quarter 2016 of approximately $75 million , which represents its estimate of the retail portion of the costs. Complaint Against System Energy In January 2017 the APSC and MPSC filed a complaint with the FERC against System Energy. The complaint seeks a reduction in the return on equity component of the Unit Power Sales Agreement pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. Entergy Arkansas also sells some of its Grand Gulf capacity and energy to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans under separate agreements. The current return on equity under the Unit Power Sales Agreement is 10.94% . The complaint alleges that the return on equity is unjust and unreasonable because current capital market and other considerations indicate that it is excessive. The complaint requests the FERC to institute proceedings to investigate the return on equity and establish a lower return on equity, and also requests that the FERC establish January 23, 2017 as a refund effective date. The complaint includes return on equity analysis that purports to establish that the range of reasonable return on equity for System Energy is between 8.37% and 8.67% . System Energy answered the complaint in February 2017 and disputes that a return on equity of 8.37% to 8.67% is just and reasonable. The LPSC and the City Council intervened in the proceeding expressing support for the complaint. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Action by the FERC is pending. Unit Power Sales Agreement In August 2017, System Energy submitted to the FERC proposed amendments to the Unit Power Sales Agreement pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. The filing proposes limited amendments to the Unit Power Sales Agreement to adopt (1) updated rates for use in calculating Grand Gulf plant depreciation and amortization expenses and (2) updated nuclear decommissioning cost annual revenue requirements, both of which are recovered through the Unit Power Sales Agreement rate formula. The proposed amendments would result in lower charges to the Utility operating companies that buy capacity and energy from System Energy under the Unit Power Sales Agreement. The proposed changes are based on updated depreciation and nuclear decommissioning studies that take into account the renewal of Grand Gulf’s operating license for a term through November 1, 2044. System Energy requested that the FERC accept the amendments effective October 1, 2017. Action by the FERC is pending.
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 Energy Cost Recovery Rider In March 2017, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01164 per kWh to $0.01547 per kWh. The APSC staff filed testimony in March 2017 recommending that the redetermined rate should be implemented with the first billing cycle of April 2017 under the normal operation of the tariff. Accordingly, the redetermined rate went into effect on March 31, 2017 pursuant to the tariff. In July 2017 the Arkansas Attorney General requested additional information to support certain of the costs included in Entergy Arkansas’s 2017 energy cost rate redetermination. Entergy Louisiana As discussed in the Form 10-K, in June 2016 the LPSC staff provided notice of audits of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. Discovery commenced in March 2017. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi attorney general filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power. The defendants have denied the allegations. In June 2017 the District Court issued a case management order setting a trial date in November 2018. Discovery is currently in progress. Entergy Texas As discussed in the Form 10-K, 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. In December 2016, Entergy Texas entered into a stipulation and settlement agreement resulting in a $6 million disallowance not associated with any particular issue raised and a refund of the over-recovery balance of $21 million as of November 30, 2016, to most customers beginning April 2017 through June 2017. The fuel reconciliation settlement was approved by the PUCT in March 2017 and the refunds were made. In June 2017, Entergy Texas filed an application for a fuel refund of approximately $30.7 million for the months of December 2016 through April 2017. For most customers, the refunds will flow through bills for the months of July 2017 through September 2017. Also in June 2017, the PUCT’s administrative law judge approved the refund on an interim basis. A final decision in this matter remains pending. 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 2016 Formula Rate Plan Filing As discussed in the Form 10-K, Entergy Arkansas is required to make a supplemental filing supporting the recovery of certain nuclear costs. In April 2017, Entergy Arkansas filed a motion consented to by all parties requesting that it be permitted to submit its supplemental filing in conjunction with its 2017 formula rate plan filing, which was subsequently made in July 2017 and is discussed below. In May 2017 the APSC approved the joint motion and proposal to review Entergy Arkansas’s supplemental filing on a concurrent schedule with the 2017 formula rate plan filing. In doing so, however, the APSC noted that a determination of whether the supplemental information supporting certain nuclear expenditures will be considered in the hearing for the 2017 formula rate plan filing or a separate hearing will be made at a later time. 2017 Formula Rate Plan Filing In July 2017, Entergy Arkansas filed with the APSC its 2017 formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2018 test period to be below the formula rate plan bandwidth. The filing projected a $129.7 million revenue requirement increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . Because the projected revenue increase exceeds the four percent annual revenue constraint for each rate class, however, Entergy Arkansas proposed a $70.9 million revenue requirement increase. Entergy Arkansas requested an order approving its proposed formula rate plan adjustment by December 13, 2017. If a final order is not issued by this date, the proposed formula rate plan adjustment will become effective January 2, 2018, subject to refund. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in September 2016, Entergy Arkansas filed an application seeking a finding from the APSC that Entergy Arkansas’s deployment of advanced metering infrastructure is in the public interest. In June 2017 the APSC staff and Arkansas Attorney General filed direct testimony. The APSC staff generally supported Entergy Arkansas’s AMI deployment conditioned on various recommendations. The Arkansas Attorney General’s consultant primarily recommended denial of Entergy Arkansas’s application but alternatively suggested recommendations in the event the APSC approves Entergy Arkansas’s proposal. Entergy Arkansas filed rebuttal testimony in June 2017, substantially accepting the APSC staff’s recommendations. In August 2017, Entergy Arkansas and the parties to the proceeding filed a joint motion to suspend the procedural schedule pending the filing with the APSC of an agreement in principle on all issues. Filings with the LPSC Retail Rates - Electric 2014 Formula Rate Plan Filing As discussed in the Form 10-K, in September 2015, Entergy Louisiana filed its formula rate plan evaluation report for Entergy Gulf States Louisiana’s and Entergy Louisiana’s 2014 calendar year operations. In June 2017 the LPSC staff and Entergy Louisiana filed an unopposed joint report of proceedings, which was accepted by the LPSC in June 2017, finalizing the results of this proceeding with no changes to rates already implemented. 2015 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. In June 2017 the LPSC staff and Entergy Louisiana filed a joint report of proceedings, which was accepted by the LPSC in June 2017, finalizing the results of the May 2016 evaluation report, interim updates, and corresponding proceedings with no changes to rates already implemented. Also, in November 2016, Entergy Louisiana filed with the LPSC a request to extend the MISO cost recovery mechanism rider provision of its formula rate plan. In March 2017 the LPSC staff submitted direct testimony generally supportive of a one-year extension of the MISO cost recovery mechanism and the intervenor in the proceeding does not oppose an extension for this period of time. In June 2017 an uncontested joint stipulation authorizing a one-year extension of the MISO cost recovery mechanism rider was filed and the LPSC approved the stipulation in July 2017. 2016 Formula Rate Plan Filing In May 2017, Entergy Louisiana filed its formula rate plan evaluation report for its 2016 calendar year operations. The evaluation report reflects an earned return on common equity of 9.84% . As such, no adjustment to base formula rate plan revenue is required. The following adjustments, however, are required under the formula rate plan: The 2016 formula rate plan evaluation report shows a decrease in formula rate plan revenue of approximately $16.9 million , comprised of a decrease in legacy Entergy Louisiana formula rate plan revenue of $3.5 million , a decrease in legacy Entergy Gulf States Louisiana formula rate plan revenue of $9.7 million , and a decrease in incremental formula rate plan revenue of $3.6 million . Additionally, the formula rate plan evaluation report calls for a decrease in the MISO cost recovery revenue requirement of $40.5 million , from the present level of $46.8 million to $6.3 million . Rates reflecting these adjustments will be implemented with the first billing cycle of September 2017, subject to refund, pending the review proceedings. Parties have intervened in the proceedings. No procedural schedule has been established. Waterford 3 Replacement Steam Generator Project See Note 2 to the financial statements in the Form 10-K for discussion of the Waterford 3 replacement steam generator project prudence review proceeding. The refund to customers of approximately $71 million as a result of the settlement approved by the LPSC was made to customers in January 2017. Following a review by the parties, an unopposed joint report of proceedings was filed by the LPSC staff and Entergy Louisiana in May 2017. In May 2017 the LPSC accepted the joint report of proceedings resolving the matter. Union Power Station 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 the decision to deactivate Willow Glen 2 and 4. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three year term permitted by MISO. This matter is pending before an ALJ, with an evidentiary hearing scheduled in August 2017. Retail Rates - Gas 2016 Rate Stabilization Plan Filing In January 2017, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2016. The filing of the evaluation report for test year 2016 reflected an earned return on common equity of 6.37% . As part of the original filing, pursuant to the extraordinary cost provision of the rate stabilization plan, Entergy Louisiana sought to recover approximately $1.5 million in deferred operation and maintenance expenses incurred to restore service and repair damage resulting from flooding and widespread rainfall in southeast Louisiana that occurred in August 2016. Entergy Louisiana requested to recover the prudently incurred August 2016 storm restoration costs over ten years, outside of the rate stabilization plan sharing provisions. As a result, Entergy Louisiana’s filing sought an annual increase in revenue of $1.4 million . Following review of the filing, except for the proposed extraordinary cost recovery, the LPSC staff confirmed Entergy Louisiana’s filing was consistent with the principles and requirements of the rate stabilization plan. The extraordinary cost recovery request associated with the 2016 flood-related deferred operation and maintenance expenses incurred for gas operations was removed from the rate stabilization plan pending LPSC consideration in a separate docket. In April 2017 the LPSC approved a joint report of proceedings and Entergy Louisiana submitted a revised evaluation report reflecting a $1.2 million annual increase in revenue with rates implemented with the first billing cycle of May 2017. In connection with the joint report of proceedings accepted by the LPSC, in May 2017, Entergy Louisiana filed an application to initiate a separate proceeding to recover the deferred operation and maintenance expenses incurred to restore service and repair damage resulting from flooding and widespread rainfall in southeast Louisiana that occurred in August 2016 through the extraordinary cost provision of the gas rate stabilization plan. A procedural schedule has been established, with a hearing in November 2017. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in November 2016, Entergy Louisiana filed an application seeking a finding from the LPSC that Entergy Louisiana’s deployment of advanced electric and gas metering infrastructure is in the public interest. The parties reached an uncontested stipulation permitting implementation of Entergy Louisiana’s proposed AMI system, with modifications to the proposed customer charge. In July 2017 the LPSC approved the stipulation. Filings with the MPSC Formula Rate Plan In March 2017, Entergy Mississippi submitted its formula rate plan 2017 test year filing and 2016 look-back filing showing Entergy Mississippi’s earned return for the historical 2016 calendar year and projected earned return for the 2017 calendar year to be within the formula rate plan bandwidth, resulting in no change in rates. In June 2017, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a stipulation that confirmed that Entergy Mississippi’s earned returns for both the 2016 look-back filing and 2017 test year were within the respective formula rate plan bandwidths. In June 2017 the MPSC approved the stipulation, which resulted in no change in rates. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in November 2016, Entergy Mississippi filed an application seeking a finding from the MPSC that Entergy Mississippi’s deployment of advanced metering infrastructure is in the public interest. In May 2017 the Mississippi Public Utilities Staff and Entergy Mississippi entered into and filed a joint stipulation supporting Entergy Mississippi’s filing, and the MPSC issued an order approving the filing without any material changes, finding that Entergy Mississippi’s deployment of AMI is in the public interest and granting a certificate of public convenience and necessity. The MPSC order also confirmed that Entergy Mississippi shall continue to include in rate base the remaining book value of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Filings with the City Council Retail Rates As discussed in the Form 10-K, in February 2017, Entergy New Orleans filed a proposed implementation plan for the Energy Smart program from April 2017 through March 2020. As part of the proposal, Entergy New Orleans requested that the City Council identify its desired level of funding for the program during this time period and approve a cost recovery mechanism. In April 2017 the City Council approved an implementation plan for the Energy Smart program from April 2017 through December 2019. The City Council directed that the $11.8 million balance reported for Energy Smart funds be used to continue funding the program for Entergy New Orleans’s legacy customers and that the Energy Smart Algiers program continue to be funded through the Algiers fuel adjustment clause, until additional customer funding is required for the legacy customers. The City Council ordered Entergy New Orleans to submit a supplemental and amended implementation plan for program years 8 and 9 of the Energy Smart program (January 2018 through December 2019) in October 2017. Following that filing, the City Council will determine a specific cost recovery mechanism for the program for both legacy and Algiers customers. The City Council will not permit Entergy New Orleans to recover lost contribution to fixed costs for program years 7, 8, or 9 of the Energy Smart program. Internal Restructuring As discussed in the Form 10-K, in July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring that 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 owned by an existing Entergy subsidiary holding company. In May 2017 the City Council adopted a resolution approving the proposed internal restructuring pursuant to an agreement in principle with the City Council advisors and certain intervenors. Pursuant to the agreement in principle, Entergy New Orleans will credit retail customers $10 million in 2017, $1.4 million in the first quarter of the year after the transaction closes, and $117,500 each month in the second year after the transaction closes until such time as new base rates go into effect as a result of the anticipated 2018 base rate case. Entergy New Orleans began crediting retail customers in June 2017. Also pursuant to the agreement in principle, if FERC approval is received prior to December 31, 2018, Entergy New Orleans will provide additional credits to retail customers of $5 million in each of the years 2018, 2019, and 2020. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in October 2016, Entergy New Orleans filed an application seeking a finding from the City Council that Entergy New Orleans’s deployment of advanced electric and gas metering infrastructure is in the public interest. In April 2017, Entergy New Orleans received intervenor testimony that was generally supportive of AMI deployment. The City Council’s advisors filed testimony in May 2017 recommending the adoption of AMI subject to certain modifications, including the denial of Entergy New Orleans’s proposed customer charge as a cost recovery mechanism. In June 2017 the procedural schedule was suspended to allow for settlement discussions. A settlement status conference is scheduled for August 2017. Filings with the PUCT Other Filings In September 2016, Entergy Texas filed with the PUCT a request to amend its transmission cost recovery factor (TCRF) rider. The proposed amended TCRF rider is designed to collect approximately $29.5 million annually from Entergy Texas’s retail customers. This amount includes the approximately $10.5 million annually that Entergy Texas is currently authorized to collect through the TCRF rider. In September 2016 the PUCT suspended the effective date of the tariff change to March 2017. In December 2016, Entergy Texas and the PUCT reached a settlement agreeing to the amended TCRF annual revenue requirement of $29.5 million . The PUCT approved the settlement and issued a final order in March 2017. Entergy Texas implemented the amended TCRF rider beginning with bills covering usage on and after March 20, 2017. In June 2017, Entergy Texas filed an application to amend its distribution cost recovery factor (DCRF) rider by increasing the total collection from $8.65 million to approximately $19 million . In July 2017, Entergy Texas, the PUCT, and the two other parties in the proceeding entered into an unopposed stipulation and settlement agreement resulting in an amended DCRF annual revenue requirement of $18.3 million , with the resulting rates effective for usage no later than October 1, 2017. PUCT action on the stipulation and settlement agreement remains pending. Advanced Metering Infrastructure (AMI) Filing In its most recent regular session, the Texas legislature enacted legislation that extends statutory support for AMI deployment to Entergy Texas and directs that if Entergy Texas elects to deploy AMI, it shall do so as rapidly as practicable. In July 2017, Entergy Texas filed an application seeking an order from the PUCT approving Entergy Texas’s deployment of AMI. Entergy Texas proposed to replace existing meters with advanced meters that enable two-way data communication; design and build a secure and reliable network to support such communications; and implement support systems. AMI is intended to serve as the foundation of Entergy Texas’s modernized power grid. The filing identified a number of quantified and unquantified benefits, with Entergy Texas showing that its AMI deployment is expected to produce nominal net operational cost savings to customers of $33 million . Entergy Texas also sought to continue to include in rate base the remaining book value, approximately $41 million at December 31, 2016, of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Entergy Texas proposed a seven-year depreciable life for the new advanced meters, the three-year deployment of which is expected to begin in 2019. Entergy Texas also proposed a surcharge tariff to recover the reasonable and necessary costs it has and will incur under the deployment plan for the full deployment of advanced meters. Further, Entergy Texas is seeking approval of fees that would be charged to customers who choose to opt out of receiving service through an advanced meter and instead receive electric service with a non-standard meter. Subject to approval by the PUCT, deployment of the communications network is expected to begin in 2018. Entergy Texas expects a decision from the PUCT by December 2017. System Agreement Cost Equalization Proceedings See the Form 10-K for a discussion of the litigation involving the System Agreement at the FERC and in federal courts. Entergy Arkansas Opportunity Sales Proceedings As discussed in the Form 10-K, in June 2009 the LPSC filed a complaint requesting 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 allocated 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 prohibited sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. The LPSC’s complaint challenges sales made beginning in 2002 and requests refunds. In April 2016 the FERC issued orders addressing requests for rehearing filed in July 2012 and an 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 August 2013 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. In May 2016, Entergy Services filed a request for rehearing of the FERC’s April 2016 order addressing the requests for rehearing filed in July 2012. Entergy Services also filed a request for clarification and/or rehearing of the FERC’s April 2016 order addressing the ALJ’s August 2013 initial decision. The APSC and the LPSC also filed requests for rehearing of the FERC’s April 2016 order. The rehearing and clarification requests filed in May 2016 are pending FERC action. Pursuant to the procedural schedule established in the case, Entergy Services re-ran intra-system bills for the ten-year period 2000-2009 to quantify the effects of the FERC's ruling. In November 2016 the LPSC submitted testimony disputing certain aspects of the calculations, and Entergy Services submitted answering testimony in January 2017. In February 2017 the FERC staff filed testimony and Entergy Services filed responsive testimony. In March 2017 the LPSC filed rebuttal testimony. A hearing was held in May 2017. In July 2017, the ALJ issued an initial decision concluding that Entergy Arkansas should pay $86 million plus interest to the other Utility operating companies. The Utility operating companies have the opportunity to challenge the ALJ’s initial decision by filing a brief on exceptions with the FERC. No payments will be made or received by the Utility operating companies until the FERC issues an order reviewing the initial decision and Entergy submits a subsequent filing to comply with that order. The effect of the FERC’s decisions thus far in the case would be that Entergy Arkansas will make payments to some or all of the other Utility operating companies. Because further proceedings will still occur in the case, the amount and recipients of payments by Entergy Arkansas are unknown at this time. Based on testimony previously submitted in the case and its assessment of the April 2016 FERC orders, in the first quarter 2016, Entergy Arkansas recorded a liability of $87 million , which includes interest, for its estimated increased costs and payment to the other Utility operating companies. This estimate is subject to change depending on how the FERC resolves the issues that are still outstanding in the case, including its review of the July 2017 initial decision. 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. Entergy Arkansas, therefore, recorded a regulatory asset in the first quarter 2016 of approximately $75 million , which represents its estimate of the retail portion of the costs. Complaint Against System Energy In January 2017 the APSC and MPSC filed a complaint with the FERC against System Energy. The complaint seeks a reduction in the return on equity component of the Unit Power Sales Agreement pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. Entergy Arkansas also sells some of its Grand Gulf capacity and energy to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans under separate agreements. The current return on equity under the Unit Power Sales Agreement is 10.94% . The complaint alleges that the return on equity is unjust and unreasonable because current capital market and other considerations indicate that it is excessive. The complaint requests the FERC to institute proceedings to investigate the return on equity and establish a lower return on equity, and also requests that the FERC establish January 23, 2017 as a refund effective date. The complaint includes return on equity analysis that purports to establish that the range of reasonable return on equity for System Energy is between 8.37% and 8.67% . System Energy answered the complaint in February 2017 and disputes that a return on equity of 8.37% to 8.67% is just and reasonable. The LPSC and the City Council intervened in the proceeding expressing support for the complaint. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Action by the FERC is pending. Unit Power Sales Agreement In August 2017, System Energy submitted to the FERC proposed amendments to the Unit Power Sales Agreement pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. The filing proposes limited amendments to the Unit Power Sales Agreement to adopt (1) updated rates for use in calculating Grand Gulf plant depreciation and amortization expenses and (2) updated nuclear decommissioning cost annual revenue requirements, both of which are recovered through the Unit Power Sales Agreement rate formula. The proposed amendments would result in lower charges to the Utility operating companies that buy capacity and energy from System Energy under the Unit Power Sales Agreement. The proposed changes are based on updated depreciation and nuclear decommissioning studies that take into account the renewal of Grand Gulf’s operating license for a term through November 1, 2044. System Energy requested that the FERC accept the amendments effective October 1, 2017. Action by the FERC is pending.
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 Energy Cost Recovery Rider In March 2017, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01164 per kWh to $0.01547 per kWh. The APSC staff filed testimony in March 2017 recommending that the redetermined rate should be implemented with the first billing cycle of April 2017 under the normal operation of the tariff. Accordingly, the redetermined rate went into effect on March 31, 2017 pursuant to the tariff. In July 2017 the Arkansas Attorney General requested additional information to support certain of the costs included in Entergy Arkansas’s 2017 energy cost rate redetermination. Entergy Louisiana As discussed in the Form 10-K, in June 2016 the LPSC staff provided notice of audits of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. Discovery commenced in March 2017. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi attorney general filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power. The defendants have denied the allegations. In June 2017 the District Court issued a case management order setting a trial date in November 2018. Discovery is currently in progress. Entergy Texas As discussed in the Form 10-K, 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. In December 2016, Entergy Texas entered into a stipulation and settlement agreement resulting in a $6 million disallowance not associated with any particular issue raised and a refund of the over-recovery balance of $21 million as of November 30, 2016, to most customers beginning April 2017 through June 2017. The fuel reconciliation settlement was approved by the PUCT in March 2017 and the refunds were made. In June 2017, Entergy Texas filed an application for a fuel refund of approximately $30.7 million for the months of December 2016 through April 2017. For most customers, the refunds will flow through bills for the months of July 2017 through September 2017. Also in June 2017, the PUCT’s administrative law judge approved the refund on an interim basis. A final decision in this matter remains pending. 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 2016 Formula Rate Plan Filing As discussed in the Form 10-K, Entergy Arkansas is required to make a supplemental filing supporting the recovery of certain nuclear costs. In April 2017, Entergy Arkansas filed a motion consented to by all parties requesting that it be permitted to submit its supplemental filing in conjunction with its 2017 formula rate plan filing, which was subsequently made in July 2017 and is discussed below. In May 2017 the APSC approved the joint motion and proposal to review Entergy Arkansas’s supplemental filing on a concurrent schedule with the 2017 formula rate plan filing. In doing so, however, the APSC noted that a determination of whether the supplemental information supporting certain nuclear expenditures will be considered in the hearing for the 2017 formula rate plan filing or a separate hearing will be made at a later time. 2017 Formula Rate Plan Filing In July 2017, Entergy Arkansas filed with the APSC its 2017 formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2018 test period to be below the formula rate plan bandwidth. The filing projected a $129.7 million revenue requirement increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . Because the projected revenue increase exceeds the four percent annual revenue constraint for each rate class, however, Entergy Arkansas proposed a $70.9 million revenue requirement increase. Entergy Arkansas requested an order approving its proposed formula rate plan adjustment by December 13, 2017. If a final order is not issued by this date, the proposed formula rate plan adjustment will become effective January 2, 2018, subject to refund. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in September 2016, Entergy Arkansas filed an application seeking a finding from the APSC that Entergy Arkansas’s deployment of advanced metering infrastructure is in the public interest. In June 2017 the APSC staff and Arkansas Attorney General filed direct testimony. The APSC staff generally supported Entergy Arkansas’s AMI deployment conditioned on various recommendations. The Arkansas Attorney General’s consultant primarily recommended denial of Entergy Arkansas’s application but alternatively suggested recommendations in the event the APSC approves Entergy Arkansas’s proposal. Entergy Arkansas filed rebuttal testimony in June 2017, substantially accepting the APSC staff’s recommendations. In August 2017, Entergy Arkansas and the parties to the proceeding filed a joint motion to suspend the procedural schedule pending the filing with the APSC of an agreement in principle on all issues. Filings with the LPSC Retail Rates - Electric 2014 Formula Rate Plan Filing As discussed in the Form 10-K, in September 2015, Entergy Louisiana filed its formula rate plan evaluation report for Entergy Gulf States Louisiana’s and Entergy Louisiana’s 2014 calendar year operations. In June 2017 the LPSC staff and Entergy Louisiana filed an unopposed joint report of proceedings, which was accepted by the LPSC in June 2017, finalizing the results of this proceeding with no changes to rates already implemented. 2015 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. In June 2017 the LPSC staff and Entergy Louisiana filed a joint report of proceedings, which was accepted by the LPSC in June 2017, finalizing the results of the May 2016 evaluation report, interim updates, and corresponding proceedings with no changes to rates already implemented. Also, in November 2016, Entergy Louisiana filed with the LPSC a request to extend the MISO cost recovery mechanism rider provision of its formula rate plan. In March 2017 the LPSC staff submitted direct testimony generally supportive of a one-year extension of the MISO cost recovery mechanism and the intervenor in the proceeding does not oppose an extension for this period of time. In June 2017 an uncontested joint stipulation authorizing a one-year extension of the MISO cost recovery mechanism rider was filed and the LPSC approved the stipulation in July 2017. 2016 Formula Rate Plan Filing In May 2017, Entergy Louisiana filed its formula rate plan evaluation report for its 2016 calendar year operations. The evaluation report reflects an earned return on common equity of 9.84% . As such, no adjustment to base formula rate plan revenue is required. The following adjustments, however, are required under the formula rate plan: The 2016 formula rate plan evaluation report shows a decrease in formula rate plan revenue of approximately $16.9 million , comprised of a decrease in legacy Entergy Louisiana formula rate plan revenue of $3.5 million , a decrease in legacy Entergy Gulf States Louisiana formula rate plan revenue of $9.7 million , and a decrease in incremental formula rate plan revenue of $3.6 million . Additionally, the formula rate plan evaluation report calls for a decrease in the MISO cost recovery revenue requirement of $40.5 million , from the present level of $46.8 million to $6.3 million . Rates reflecting these adjustments will be implemented with the first billing cycle of September 2017, subject to refund, pending the review proceedings. Parties have intervened in the proceedings. No procedural schedule has been established. Waterford 3 Replacement Steam Generator Project See Note 2 to the financial statements in the Form 10-K for discussion of the Waterford 3 replacement steam generator project prudence review proceeding. The refund to customers of approximately $71 million as a result of the settlement approved by the LPSC was made to customers in January 2017. Following a review by the parties, an unopposed joint report of proceedings was filed by the LPSC staff and Entergy Louisiana in May 2017. In May 2017 the LPSC accepted the joint report of proceedings resolving the matter. Union Power Station 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 the decision to deactivate Willow Glen 2 and 4. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three year term permitted by MISO. This matter is pending before an ALJ, with an evidentiary hearing scheduled in August 2017. Retail Rates - Gas 2016 Rate Stabilization Plan Filing In January 2017, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2016. The filing of the evaluation report for test year 2016 reflected an earned return on common equity of 6.37% . As part of the original filing, pursuant to the extraordinary cost provision of the rate stabilization plan, Entergy Louisiana sought to recover approximately $1.5 million in deferred operation and maintenance expenses incurred to restore service and repair damage resulting from flooding and widespread rainfall in southeast Louisiana that occurred in August 2016. Entergy Louisiana requested to recover the prudently incurred August 2016 storm restoration costs over ten years, outside of the rate stabilization plan sharing provisions. As a result, Entergy Louisiana’s filing sought an annual increase in revenue of $1.4 million . Following review of the filing, except for the proposed extraordinary cost recovery, the LPSC staff confirmed Entergy Louisiana’s filing was consistent with the principles and requirements of the rate stabilization plan. The extraordinary cost recovery request associated with the 2016 flood-related deferred operation and maintenance expenses incurred for gas operations was removed from the rate stabilization plan pending LPSC consideration in a separate docket. In April 2017 the LPSC approved a joint report of proceedings and Entergy Louisiana submitted a revised evaluation report reflecting a $1.2 million annual increase in revenue with rates implemented with the first billing cycle of May 2017. In connection with the joint report of proceedings accepted by the LPSC, in May 2017, Entergy Louisiana filed an application to initiate a separate proceeding to recover the deferred operation and maintenance expenses incurred to restore service and repair damage resulting from flooding and widespread rainfall in southeast Louisiana that occurred in August 2016 through the extraordinary cost provision of the gas rate stabilization plan. A procedural schedule has been established, with a hearing in November 2017. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in November 2016, Entergy Louisiana filed an application seeking a finding from the LPSC that Entergy Louisiana’s deployment of advanced electric and gas metering infrastructure is in the public interest. The parties reached an uncontested stipulation permitting implementation of Entergy Louisiana’s proposed AMI system, with modifications to the proposed customer charge. In July 2017 the LPSC approved the stipulation. Filings with the MPSC Formula Rate Plan In March 2017, Entergy Mississippi submitted its formula rate plan 2017 test year filing and 2016 look-back filing showing Entergy Mississippi’s earned return for the historical 2016 calendar year and projected earned return for the 2017 calendar year to be within the formula rate plan bandwidth, resulting in no change in rates. In June 2017, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a stipulation that confirmed that Entergy Mississippi’s earned returns for both the 2016 look-back filing and 2017 test year were within the respective formula rate plan bandwidths. In June 2017 the MPSC approved the stipulation, which resulted in no change in rates. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in November 2016, Entergy Mississippi filed an application seeking a finding from the MPSC that Entergy Mississippi’s deployment of advanced metering infrastructure is in the public interest. In May 2017 the Mississippi Public Utilities Staff and Entergy Mississippi entered into and filed a joint stipulation supporting Entergy Mississippi’s filing, and the MPSC issued an order approving the filing without any material changes, finding that Entergy Mississippi’s deployment of AMI is in the public interest and granting a certificate of public convenience and necessity. The MPSC order also confirmed that Entergy Mississippi shall continue to include in rate base the remaining book value of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Filings with the City Council Retail Rates As discussed in the Form 10-K, in February 2017, Entergy New Orleans filed a proposed implementation plan for the Energy Smart program from April 2017 through March 2020. As part of the proposal, Entergy New Orleans requested that the City Council identify its desired level of funding for the program during this time period and approve a cost recovery mechanism. In April 2017 the City Council approved an implementation plan for the Energy Smart program from April 2017 through December 2019. The City Council directed that the $11.8 million balance reported for Energy Smart funds be used to continue funding the program for Entergy New Orleans’s legacy customers and that the Energy Smart Algiers program continue to be funded through the Algiers fuel adjustment clause, until additional customer funding is required for the legacy customers. The City Council ordered Entergy New Orleans to submit a supplemental and amended implementation plan for program years 8 and 9 of the Energy Smart program (January 2018 through December 2019) in October 2017. Following that filing, the City Council will determine a specific cost recovery mechanism for the program for both legacy and Algiers customers. The City Council will not permit Entergy New Orleans to recover lost contribution to fixed costs for program years 7, 8, or 9 of the Energy Smart program. Internal Restructuring As discussed in the Form 10-K, in July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring that 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 owned by an existing Entergy subsidiary holding company. In May 2017 the City Council adopted a resolution approving the proposed internal restructuring pursuant to an agreement in principle with the City Council advisors and certain intervenors. Pursuant to the agreement in principle, Entergy New Orleans will credit retail customers $10 million in 2017, $1.4 million in the first quarter of the year after the transaction closes, and $117,500 each month in the second year after the transaction closes until such time as new base rates go into effect as a result of the anticipated 2018 base rate case. Entergy New Orleans began crediting retail customers in June 2017. Also pursuant to the agreement in principle, if FERC approval is received prior to December 31, 2018, Entergy New Orleans will provide additional credits to retail customers of $5 million in each of the years 2018, 2019, and 2020. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in October 2016, Entergy New Orleans filed an application seeking a finding from the City Council that Entergy New Orleans’s deployment of advanced electric and gas metering infrastructure is in the public interest. In April 2017, Entergy New Orleans received intervenor testimony that was generally supportive of AMI deployment. The City Council’s advisors filed testimony in May 2017 recommending the adoption of AMI subject to certain modifications, including the denial of Entergy New Orleans’s proposed customer charge as a cost recovery mechanism. In June 2017 the procedural schedule was suspended to allow for settlement discussions. A settlement status conference is scheduled for August 2017. Filings with the PUCT Other Filings In September 2016, Entergy Texas filed with the PUCT a request to amend its transmission cost recovery factor (TCRF) rider. The proposed amended TCRF rider is designed to collect approximately $29.5 million annually from Entergy Texas’s retail customers. This amount includes the approximately $10.5 million annually that Entergy Texas is currently authorized to collect through the TCRF rider. In September 2016 the PUCT suspended the effective date of the tariff change to March 2017. In December 2016, Entergy Texas and the PUCT reached a settlement agreeing to the amended TCRF annual revenue requirement of $29.5 million . The PUCT approved the settlement and issued a final order in March 2017. Entergy Texas implemented the amended TCRF rider beginning with bills covering usage on and after March 20, 2017. In June 2017, Entergy Texas filed an application to amend its distribution cost recovery factor (DCRF) rider by increasing the total collection from $8.65 million to approximately $19 million . In July 2017, Entergy Texas, the PUCT, and the two other parties in the proceeding entered into an unopposed stipulation and settlement agreement resulting in an amended DCRF annual revenue requirement of $18.3 million , with the resulting rates effective for usage no later than October 1, 2017. PUCT action on the stipulation and settlement agreement remains pending. Advanced Metering Infrastructure (AMI) Filing In its most recent regular session, the Texas legislature enacted legislation that extends statutory support for AMI deployment to Entergy Texas and directs that if Entergy Texas elects to deploy AMI, it shall do so as rapidly as practicable. In July 2017, Entergy Texas filed an application seeking an order from the PUCT approving Entergy Texas’s deployment of AMI. Entergy Texas proposed to replace existing meters with advanced meters that enable two-way data communication; design and build a secure and reliable network to support such communications; and implement support systems. AMI is intended to serve as the foundation of Entergy Texas’s modernized power grid. The filing identified a number of quantified and unquantified benefits, with Entergy Texas showing that its AMI deployment is expected to produce nominal net operational cost savings to customers of $33 million . Entergy Texas also sought to continue to include in rate base the remaining book value, approximately $41 million at December 31, 2016, of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Entergy Texas proposed a seven-year depreciable life for the new advanced meters, the three-year deployment of which is expected to begin in 2019. Entergy Texas also proposed a surcharge tariff to recover the reasonable and necessary costs it has and will incur under the deployment plan for the full deployment of advanced meters. Further, Entergy Texas is seeking approval of fees that would be charged to customers who choose to opt out of receiving service through an advanced meter and instead receive electric service with a non-standard meter. Subject to approval by the PUCT, deployment of the communications network is expected to begin in 2018. Entergy Texas expects a decision from the PUCT by December 2017. System Agreement Cost Equalization Proceedings See the Form 10-K for a discussion of the litigation involving the System Agreement at the FERC and in federal courts. Entergy Arkansas Opportunity Sales Proceedings As discussed in the Form 10-K, in June 2009 the LPSC filed a complaint requesting 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 allocated 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 prohibited sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. The LPSC’s complaint challenges sales made beginning in 2002 and requests refunds. In April 2016 the FERC issued orders addressing requests for rehearing filed in July 2012 and an 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 August 2013 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. In May 2016, Entergy Services filed a request for rehearing of the FERC’s April 2016 order addressing the requests for rehearing filed in July 2012. Entergy Services also filed a request for clarification and/or rehearing of the FERC’s April 2016 order addressing the ALJ’s August 2013 initial decision. The APSC and the LPSC also filed requests for rehearing of the FERC’s April 2016 order. The rehearing and clarification requests filed in May 2016 are pending FERC action. Pursuant to the procedural schedule established in the case, Entergy Services re-ran intra-system bills for the ten-year period 2000-2009 to quantify the effects of the FERC's ruling. In November 2016 the LPSC submitted testimony disputing certain aspects of the calculations, and Entergy Services submitted answering testimony in January 2017. In February 2017 the FERC staff filed testimony and Entergy Services filed responsive testimony. In March 2017 the LPSC filed rebuttal testimony. A hearing was held in May 2017. In July 2017, the ALJ issued an initial decision concluding that Entergy Arkansas should pay $86 million plus interest to the other Utility operating companies. The Utility operating companies have the opportunity to challenge the ALJ’s initial decision by filing a brief on exceptions with the FERC. No payments will be made or received by the Utility operating companies until the FERC issues an order reviewing the initial decision and Entergy submits a subsequent filing to comply with that order. The effect of the FERC’s decisions thus far in the case would be that Entergy Arkansas will make payments to some or all of the other Utility operating companies. Because further proceedings will still occur in the case, the amount and recipients of payments by Entergy Arkansas are unknown at this time. Based on testimony previously submitted in the case and its assessment of the April 2016 FERC orders, in the first quarter 2016, Entergy Arkansas recorded a liability of $87 million , which includes interest, for its estimated increased costs and payment to the other Utility operating companies. This estimate is subject to change depending on how the FERC resolves the issues that are still outstanding in the case, including its review of the July 2017 initial decision. 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. Entergy Arkansas, therefore, recorded a regulatory asset in the first quarter 2016 of approximately $75 million , which represents its estimate of the retail portion of the costs. Complaint Against System Energy In January 2017 the APSC and MPSC filed a complaint with the FERC against System Energy. The complaint seeks a reduction in the return on equity component of the Unit Power Sales Agreement pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. Entergy Arkansas also sells some of its Grand Gulf capacity and energy to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans under separate agreements. The current return on equity under the Unit Power Sales Agreement is 10.94% . The complaint alleges that the return on equity is unjust and unreasonable because current capital market and other considerations indicate that it is excessive. The complaint requests the FERC to institute proceedings to investigate the return on equity and establish a lower return on equity, and also requests that the FERC establish January 23, 2017 as a refund effective date. The complaint includes return on equity analysis that purports to establish that the range of reasonable return on equity for System Energy is between 8.37% and 8.67% . System Energy answered the complaint in February 2017 and disputes that a return on equity of 8.37% to 8.67% is just and reasonable. The LPSC and the City Council intervened in the proceeding expressing support for the complaint. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Action by the FERC is pending. Unit Power Sales Agreement In August 2017, System Energy submitted to the FERC proposed amendments to the Unit Power Sales Agreement pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. The filing proposes limited amendments to the Unit Power Sales Agreement to adopt (1) updated rates for use in calculating Grand Gulf plant depreciation and amortization expenses and (2) updated nuclear decommissioning cost annual revenue requirements, both of which are recovered through the Unit Power Sales Agreement rate formula. The proposed amendments would result in lower charges to the Utility operating companies that buy capacity and energy from System Energy under the Unit Power Sales Agreement. The proposed changes are based on updated depreciation and nuclear decommissioning studies that take into account the renewal of Grand Gulf’s operating license for a term through November 1, 2044. System Energy requested that the FERC accept the amendments effective October 1, 2017. Action by the FERC is pending.
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 Energy Cost Recovery Rider In March 2017, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01164 per kWh to $0.01547 per kWh. The APSC staff filed testimony in March 2017 recommending that the redetermined rate should be implemented with the first billing cycle of April 2017 under the normal operation of the tariff. Accordingly, the redetermined rate went into effect on March 31, 2017 pursuant to the tariff. In July 2017 the Arkansas Attorney General requested additional information to support certain of the costs included in Entergy Arkansas’s 2017 energy cost rate redetermination. Entergy Louisiana As discussed in the Form 10-K, in June 2016 the LPSC staff provided notice of audits of Entergy Louisiana’s fuel adjustment clause filings and purchased gas adjustment clause filings. Discovery commenced in March 2017. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi attorney general filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power. The defendants have denied the allegations. In June 2017 the District Court issued a case management order setting a trial date in November 2018. Discovery is currently in progress. Entergy Texas As discussed in the Form 10-K, 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. In December 2016, Entergy Texas entered into a stipulation and settlement agreement resulting in a $6 million disallowance not associated with any particular issue raised and a refund of the over-recovery balance of $21 million as of November 30, 2016, to most customers beginning April 2017 through June 2017. The fuel reconciliation settlement was approved by the PUCT in March 2017 and the refunds were made. In June 2017, Entergy Texas filed an application for a fuel refund of approximately $30.7 million for the months of December 2016 through April 2017. For most customers, the refunds will flow through bills for the months of July 2017 through September 2017. Also in June 2017, the PUCT’s administrative law judge approved the refund on an interim basis. A final decision in this matter remains pending. 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 2016 Formula Rate Plan Filing As discussed in the Form 10-K, Entergy Arkansas is required to make a supplemental filing supporting the recovery of certain nuclear costs. In April 2017, Entergy Arkansas filed a motion consented to by all parties requesting that it be permitted to submit its supplemental filing in conjunction with its 2017 formula rate plan filing, which was subsequently made in July 2017 and is discussed below. In May 2017 the APSC approved the joint motion and proposal to review Entergy Arkansas’s supplemental filing on a concurrent schedule with the 2017 formula rate plan filing. In doing so, however, the APSC noted that a determination of whether the supplemental information supporting certain nuclear expenditures will be considered in the hearing for the 2017 formula rate plan filing or a separate hearing will be made at a later time. 2017 Formula Rate Plan Filing In July 2017, Entergy Arkansas filed with the APSC its 2017 formula rate plan filing showing Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2018 test period to be below the formula rate plan bandwidth. The filing projected a $129.7 million revenue requirement increase to achieve Entergy Arkansas’s target earned return on common equity of 9.75% . Because the projected revenue increase exceeds the four percent annual revenue constraint for each rate class, however, Entergy Arkansas proposed a $70.9 million revenue requirement increase. Entergy Arkansas requested an order approving its proposed formula rate plan adjustment by December 13, 2017. If a final order is not issued by this date, the proposed formula rate plan adjustment will become effective January 2, 2018, subject to refund. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in September 2016, Entergy Arkansas filed an application seeking a finding from the APSC that Entergy Arkansas’s deployment of advanced metering infrastructure is in the public interest. In June 2017 the APSC staff and Arkansas Attorney General filed direct testimony. The APSC staff generally supported Entergy Arkansas’s AMI deployment conditioned on various recommendations. The Arkansas Attorney General’s consultant primarily recommended denial of Entergy Arkansas’s application but alternatively suggested recommendations in the event the APSC approves Entergy Arkansas’s proposal. Entergy Arkansas filed rebuttal testimony in June 2017, substantially accepting the APSC staff’s recommendations. In August 2017, Entergy Arkansas and the parties to the proceeding filed a joint motion to suspend the procedural schedule pending the filing with the APSC of an agreement in principle on all issues. Filings with the LPSC Retail Rates - Electric 2014 Formula Rate Plan Filing As discussed in the Form 10-K, in September 2015, Entergy Louisiana filed its formula rate plan evaluation report for Entergy Gulf States Louisiana’s and Entergy Louisiana’s 2014 calendar year operations. In June 2017 the LPSC staff and Entergy Louisiana filed an unopposed joint report of proceedings, which was accepted by the LPSC in June 2017, finalizing the results of this proceeding with no changes to rates already implemented. 2015 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2016, Entergy Louisiana filed its formula rate plan evaluation report for its 2015 calendar year operations. In June 2017 the LPSC staff and Entergy Louisiana filed a joint report of proceedings, which was accepted by the LPSC in June 2017, finalizing the results of the May 2016 evaluation report, interim updates, and corresponding proceedings with no changes to rates already implemented. Also, in November 2016, Entergy Louisiana filed with the LPSC a request to extend the MISO cost recovery mechanism rider provision of its formula rate plan. In March 2017 the LPSC staff submitted direct testimony generally supportive of a one-year extension of the MISO cost recovery mechanism and the intervenor in the proceeding does not oppose an extension for this period of time. In June 2017 an uncontested joint stipulation authorizing a one-year extension of the MISO cost recovery mechanism rider was filed and the LPSC approved the stipulation in July 2017. 2016 Formula Rate Plan Filing In May 2017, Entergy Louisiana filed its formula rate plan evaluation report for its 2016 calendar year operations. The evaluation report reflects an earned return on common equity of 9.84% . As such, no adjustment to base formula rate plan revenue is required. The following adjustments, however, are required under the formula rate plan: The 2016 formula rate plan evaluation report shows a decrease in formula rate plan revenue of approximately $16.9 million , comprised of a decrease in legacy Entergy Louisiana formula rate plan revenue of $3.5 million , a decrease in legacy Entergy Gulf States Louisiana formula rate plan revenue of $9.7 million , and a decrease in incremental formula rate plan revenue of $3.6 million . Additionally, the formula rate plan evaluation report calls for a decrease in the MISO cost recovery revenue requirement of $40.5 million , from the present level of $46.8 million to $6.3 million . Rates reflecting these adjustments will be implemented with the first billing cycle of September 2017, subject to refund, pending the review proceedings. Parties have intervened in the proceedings. No procedural schedule has been established. Waterford 3 Replacement Steam Generator Project See Note 2 to the financial statements in the Form 10-K for discussion of the Waterford 3 replacement steam generator project prudence review proceeding. The refund to customers of approximately $71 million as a result of the settlement approved by the LPSC was made to customers in January 2017. Following a review by the parties, an unopposed joint report of proceedings was filed by the LPSC staff and Entergy Louisiana in May 2017. In May 2017 the LPSC accepted the joint report of proceedings resolving the matter. Union Power Station 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 the decision to deactivate Willow Glen 2 and 4. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three year term permitted by MISO. This matter is pending before an ALJ, with an evidentiary hearing scheduled in August 2017. Retail Rates - Gas 2016 Rate Stabilization Plan Filing In January 2017, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2016. The filing of the evaluation report for test year 2016 reflected an earned return on common equity of 6.37% . As part of the original filing, pursuant to the extraordinary cost provision of the rate stabilization plan, Entergy Louisiana sought to recover approximately $1.5 million in deferred operation and maintenance expenses incurred to restore service and repair damage resulting from flooding and widespread rainfall in southeast Louisiana that occurred in August 2016. Entergy Louisiana requested to recover the prudently incurred August 2016 storm restoration costs over ten years, outside of the rate stabilization plan sharing provisions. As a result, Entergy Louisiana’s filing sought an annual increase in revenue of $1.4 million . Following review of the filing, except for the proposed extraordinary cost recovery, the LPSC staff confirmed Entergy Louisiana’s filing was consistent with the principles and requirements of the rate stabilization plan. The extraordinary cost recovery request associated with the 2016 flood-related deferred operation and maintenance expenses incurred for gas operations was removed from the rate stabilization plan pending LPSC consideration in a separate docket. In April 2017 the LPSC approved a joint report of proceedings and Entergy Louisiana submitted a revised evaluation report reflecting a $1.2 million annual increase in revenue with rates implemented with the first billing cycle of May 2017. In connection with the joint report of proceedings accepted by the LPSC, in May 2017, Entergy Louisiana filed an application to initiate a separate proceeding to recover the deferred operation and maintenance expenses incurred to restore service and repair damage resulting from flooding and widespread rainfall in southeast Louisiana that occurred in August 2016 through the extraordinary cost provision of the gas rate stabilization plan. A procedural schedule has been established, with a hearing in November 2017. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in November 2016, Entergy Louisiana filed an application seeking a finding from the LPSC that Entergy Louisiana’s deployment of advanced electric and gas metering infrastructure is in the public interest. The parties reached an uncontested stipulation permitting implementation of Entergy Louisiana’s proposed AMI system, with modifications to the proposed customer charge. In July 2017 the LPSC approved the stipulation. Filings with the MPSC Formula Rate Plan In March 2017, Entergy Mississippi submitted its formula rate plan 2017 test year filing and 2016 look-back filing showing Entergy Mississippi’s earned return for the historical 2016 calendar year and projected earned return for the 2017 calendar year to be within the formula rate plan bandwidth, resulting in no change in rates. In June 2017, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a stipulation that confirmed that Entergy Mississippi’s earned returns for both the 2016 look-back filing and 2017 test year were within the respective formula rate plan bandwidths. In June 2017 the MPSC approved the stipulation, which resulted in no change in rates. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in November 2016, Entergy Mississippi filed an application seeking a finding from the MPSC that Entergy Mississippi’s deployment of advanced metering infrastructure is in the public interest. In May 2017 the Mississippi Public Utilities Staff and Entergy Mississippi entered into and filed a joint stipulation supporting Entergy Mississippi’s filing, and the MPSC issued an order approving the filing without any material changes, finding that Entergy Mississippi’s deployment of AMI is in the public interest and granting a certificate of public convenience and necessity. The MPSC order also confirmed that Entergy Mississippi shall continue to include in rate base the remaining book value of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Filings with the City Council Retail Rates As discussed in the Form 10-K, in February 2017, Entergy New Orleans filed a proposed implementation plan for the Energy Smart program from April 2017 through March 2020. As part of the proposal, Entergy New Orleans requested that the City Council identify its desired level of funding for the program during this time period and approve a cost recovery mechanism. In April 2017 the City Council approved an implementation plan for the Energy Smart program from April 2017 through December 2019. The City Council directed that the $11.8 million balance reported for Energy Smart funds be used to continue funding the program for Entergy New Orleans’s legacy customers and that the Energy Smart Algiers program continue to be funded through the Algiers fuel adjustment clause, until additional customer funding is required for the legacy customers. The City Council ordered Entergy New Orleans to submit a supplemental and amended implementation plan for program years 8 and 9 of the Energy Smart program (January 2018 through December 2019) in October 2017. Following that filing, the City Council will determine a specific cost recovery mechanism for the program for both legacy and Algiers customers. The City Council will not permit Entergy New Orleans to recover lost contribution to fixed costs for program years 7, 8, or 9 of the Energy Smart program. Internal Restructuring As discussed in the Form 10-K, in July 2016, Entergy New Orleans filed an application with the City Council seeking authorization to undertake a restructuring that 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 owned by an existing Entergy subsidiary holding company. In May 2017 the City Council adopted a resolution approving the proposed internal restructuring pursuant to an agreement in principle with the City Council advisors and certain intervenors. Pursuant to the agreement in principle, Entergy New Orleans will credit retail customers $10 million in 2017, $1.4 million in the first quarter of the year after the transaction closes, and $117,500 each month in the second year after the transaction closes until such time as new base rates go into effect as a result of the anticipated 2018 base rate case. Entergy New Orleans began crediting retail customers in June 2017. Also pursuant to the agreement in principle, if FERC approval is received prior to December 31, 2018, Entergy New Orleans will provide additional credits to retail customers of $5 million in each of the years 2018, 2019, and 2020. Advanced Metering Infrastructure (AMI) Filing As discussed in the Form 10-K, in October 2016, Entergy New Orleans filed an application seeking a finding from the City Council that Entergy New Orleans’s deployment of advanced electric and gas metering infrastructure is in the public interest. In April 2017, Entergy New Orleans received intervenor testimony that was generally supportive of AMI deployment. The City Council’s advisors filed testimony in May 2017 recommending the adoption of AMI subject to certain modifications, including the denial of Entergy New Orleans’s proposed customer charge as a cost recovery mechanism. In June 2017 the procedural schedule was suspended to allow for settlement discussions. A settlement status conference is scheduled for August 2017. Filings with the PUCT Other Filings In September 2016, Entergy Texas filed with the PUCT a request to amend its transmission cost recovery factor (TCRF) rider. The proposed amended TCRF rider is designed to collect approximately $29.5 million annually from Entergy Texas’s retail customers. This amount includes the approximately $10.5 million annually that Entergy Texas is currently authorized to collect through the TCRF rider. In September 2016 the PUCT suspended the effective date of the tariff change to March 2017. In December 2016, Entergy Texas and the PUCT reached a settlement agreeing to the amended TCRF annual revenue requirement of $29.5 million . The PUCT approved the settlement and issued a final order in March 2017. Entergy Texas implemented the amended TCRF rider beginning with bills covering usage on and after March 20, 2017. In June 2017, Entergy Texas filed an application to amend its distribution cost recovery factor (DCRF) rider by increasing the total collection from $8.65 million to approximately $19 million . In July 2017, Entergy Texas, the PUCT, and the two other parties in the proceeding entered into an unopposed stipulation and settlement agreement resulting in an amended DCRF annual revenue requirement of $18.3 million , with the resulting rates effective for usage no later than October 1, 2017. PUCT action on the stipulation and settlement agreement remains pending. Advanced Metering Infrastructure (AMI) Filing In its most recent regular session, the Texas legislature enacted legislation that extends statutory support for AMI deployment to Entergy Texas and directs that if Entergy Texas elects to deploy AMI, it shall do so as rapidly as practicable. In July 2017, Entergy Texas filed an application seeking an order from the PUCT approving Entergy Texas’s deployment of AMI. Entergy Texas proposed to replace existing meters with advanced meters that enable two-way data communication; design and build a secure and reliable network to support such communications; and implement support systems. AMI is intended to serve as the foundation of Entergy Texas’s modernized power grid. The filing identified a number of quantified and unquantified benefits, with Entergy Texas showing that its AMI deployment is expected to produce nominal net operational cost savings to customers of $33 million . Entergy Texas also sought to continue to include in rate base the remaining book value, approximately $41 million at December 31, 2016, of existing meters that will be retired as part of the AMI deployment and also to depreciate those assets using current depreciation rates. Entergy Texas proposed a seven-year depreciable life for the new advanced meters, the three-year deployment of which is expected to begin in 2019. Entergy Texas also proposed a surcharge tariff to recover the reasonable and necessary costs it has and will incur under the deployment plan for the full deployment of advanced meters. Further, Entergy Texas is seeking approval of fees that would be charged to customers who choose to opt out of receiving service through an advanced meter and instead receive electric service with a non-standard meter. Subject to approval by the PUCT, deployment of the communications network is expected to begin in 2018. Entergy Texas expects a decision from the PUCT by December 2017. System Agreement Cost Equalization Proceedings See the Form 10-K for a discussion of the litigation involving the System Agreement at the FERC and in federal courts. Entergy Arkansas Opportunity Sales Proceedings As discussed in the Form 10-K, in June 2009 the LPSC filed a complaint requesting 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 allocated 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 prohibited sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. The LPSC’s complaint challenges sales made beginning in 2002 and requests refunds. In April 2016 the FERC issued orders addressing requests for rehearing filed in July 2012 and an 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 August 2013 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. In May 2016, Entergy Services filed a request for rehearing of the FERC’s April 2016 order addressing the requests for rehearing filed in July 2012. Entergy Services also filed a request for clarification and/or rehearing of the FERC’s April 2016 order addressing the ALJ’s August 2013 initial decision. The APSC and the LPSC also filed requests for rehearing of the FERC’s April 2016 order. The rehearing and clarification requests filed in May 2016 are pending FERC action. Pursuant to the procedural schedule established in the case, Entergy Services re-ran intra-system bills for the ten-year period 2000-2009 to quantify the effects of the FERC's ruling. In November 2016 the LPSC submitted testimony disputing certain aspects of the calculations, and Entergy Services submitted answering testimony in January 2017. In February 2017 the FERC staff filed testimony and Entergy Services filed responsive testimony. In March 2017 the LPSC filed rebuttal testimony. A hearing was held in May 2017. In July 2017, the ALJ issued an initial decision concluding that Entergy Arkansas should pay $86 million plus interest to the other Utility operating companies. The Utility operating companies have the opportunity to challenge the ALJ’s initial decision by filing a brief on exceptions with the FERC. No payments will be made or received by the Utility operating companies until the FERC issues an order reviewing the initial decision and Entergy submits a subsequent filing to comply with that order. The effect of the FERC’s decisions thus far in the case would be that Entergy Arkansas will make payments to some or all of the other Utility operating companies. Because further proceedings will still occur in the case, the amount and recipients of payments by Entergy Arkansas are unknown at this time. Based on testimony previously submitted in the case and its assessment of the April 2016 FERC orders, in the first quarter 2016, Entergy Arkansas recorded a liability of $87 million , which includes interest, for its estimated increased costs and payment to the other Utility operating companies. This estimate is subject to change depending on how the FERC resolves the issues that are still outstanding in the case, including its review of the July 2017 initial decision. 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. Entergy Arkansas, therefore, recorded a regulatory asset in the first quarter 2016 of approximately $75 million , which represents its estimate of the retail portion of the costs. Complaint Against System Energy In January 2017 the APSC and MPSC filed a complaint with the FERC against System Energy. The complaint seeks a reduction in the return on equity component of the Unit Power Sales Agreement pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. Entergy Arkansas also sells some of its Grand Gulf capacity and energy to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans under separate agreements. The current return on equity under the Unit Power Sales Agreement is 10.94% . The complaint alleges that the return on equity is unjust and unreasonable because current capital market and other considerations indicate that it is excessive. The complaint requests the FERC to institute proceedings to investigate the return on equity and establish a lower return on equity, and also requests that the FERC establish January 23, 2017 as a refund effective date. The complaint includes return on equity analysis that purports to establish that the range of reasonable return on equity for System Energy is between 8.37% and 8.67% . System Energy answered the complaint in February 2017 and disputes that a return on equity of 8.37% to 8.67% is just and reasonable. The LPSC and the City Council intervened in the proceeding expressing support for the complaint. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Action by the FERC is pending. Unit Power Sales Agreement In August 2017, System Energy submitted to the FERC proposed amendments to the Unit Power Sales Agreement pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. The filing proposes limited amendments to the Unit Power Sales Agreement to adopt (1) updated rates for use in calculating Grand Gulf plant depreciation and amortization expenses and (2) updated nuclear decommissioning cost annual revenue requirements, both of which are recovered through the Unit Power Sales Agreement rate formula. The proposed amendments would result in lower charges to the Utility operating companies that buy capacity and energy from System Energy under the Unit Power Sales Agreement. The proposed changes are based on updated depreciation and nuclear decommissioning studies that take into account the renewal of Grand Gulf’s operating license for a term through November 1, 2044. System Energy requested that the FERC accept the amendments effective October 1, 2017. Action by the FERC is pending.

Equity

Equity	6 Months Ended
	Jun. 30, 2017
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, 2017 2016 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $409.9 179.5 $2.28 $567.3 178.8 $3.17 Average dilutive effect of: Stock options 0.2 — 0.2 — Other equity plans 0.5 (0.01 ) 0.5 (0.01 ) Diluted earnings per share $409.9 180.2 $2.27 $567.3 179.5 $3.16 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 2.5 million for the three months ended June 30, 2017 and approximately 4.1 million for the three months ended June 30, 2016 . For the Six Months Ended June 30, 2017 2016 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $492.5 179.4 $2.75 $797.3 178.7 $4.46 Average dilutive effect of: Stock options 0.2 — 0.1 — Other equity plans 0.4 (0.01 ) 0.4 (0.01 ) Diluted earnings per share $492.5 180.0 $2.74 $797.3 179.2 $4.45 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 3.7 million for the six months ended June 30, 2017 and approximately 5.1 million for the six months ended June 30, 2016 . 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, 2017 , Entergy Corporation issued 390,013 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, 2017 . Retained Earnings On July 28, 2017, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.87 per share, payable on September 1, 2017, to holders of record as of August 10, 2017. 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, 2017 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, April 1, 2017 $3,465 ($460,814 ) $467,561 $748 $10,960 Other comprehensive income (loss) before reclassifications 28,057 — 33,870 (748 ) 61,179 Amounts reclassified from accumulated other comprehensive income (loss) (8,108 ) 10,916 (22,174 ) — (19,366 ) Net other comprehensive income (loss) for the period 19,949 10,916 11,696 (748 ) 41,813 Ending balance, June 30, 2017 $23,414 ($449,898 ) $479,257 $— $52,773 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 six months ended June 30, 2017 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, January 1, 2017 $3,993 ($469,446 ) $429,734 $748 ($34,971 ) Other comprehensive income (loss) before reclassifications 60,665 — 73,742 (748 ) 133,659 Amounts reclassified from accumulated other comprehensive income (loss) (41,244 ) 19,548 (24,219 ) — (45,915 ) Net other comprehensive income (loss) for the period 19,421 19,548 49,523 (748 ) 87,744 Ending balance, June 30, 2017 $23,414 ($449,898 ) $479,257 $— $52,773 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 Louisiana for the three months ended June 30, 2017 and 2016: Pension and Other 2017 2016 (In Thousands) Beginning balance, April 1, ($48,812 ) ($56,675 ) Amounts reclassified from accumulated other (310 ) (230 ) Net other comprehensive income (loss) for the period (310 ) (230 ) Ending balance, June 30, ($49,122 ) ($56,905 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2017 and 2016: Pension and Other 2017 2016 (In Thousands) Beginning balance, January 1, ($48,442 ) ($56,412 ) Amounts reclassified from accumulated other (680 ) (493 ) Net other comprehensive income (loss) for the period (680 ) (493 ) Ending balance, June 30, ($49,122 ) ($56,905 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended June 30, 2017 and 2016 are as follows: Amounts reclassified Income Statement Location 2017 2016 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $12,695 $45,975 Competitive business operating revenues Interest rate swaps (219 ) 30 Miscellaneous - net Total realized gain (loss) on cash flow hedges 12,476 46,005 (4,368 ) (16,102 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $8,108 $29,903 Pension and other postretirement liabilities Amortization of prior-service credit $6,564 $7,355 (a) Amortization of loss (21,554 ) (15,177 ) (a) Settlement loss (1,765 ) — (a) Total amortization (16,755 ) (7,822 ) 5,839 2,779 Income taxes Total amortization (net of tax) ($10,916 ) ($5,043 ) Net unrealized investment gain (loss) Realized gain (loss) $43,479 $6,000 Interest and investment income (21,305 ) (2,939 ) Income taxes Total realized investment gain (loss) (net of tax) $22,174 $3,061 Total reclassifications for the period (net of tax) $19,366 $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 six months ended June 30, 2017 and 2016 are as follows: Amounts reclassified from AOCI Income Statement Location 2017 2016 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $63,922 $199,933 Competitive business operating revenues Interest rate swaps (469 ) (370 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 63,453 199,563 (22,209 ) (69,847 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $41,244 $129,716 Pension and other postretirement liabilities Amortization of prior-service credit $13,126 $14,710 (a) Amortization of loss (43,125 ) (30,352 ) (a) Settlement loss (1,765 ) — (a) Total amortization (31,764 ) (15,642 ) 12,216 3,037 Income taxes Total amortization (net of tax) ($19,548 ) ($12,605 ) Net unrealized investment gain (loss) Realized gain (loss) $47,489 $9,850 Interest and investment income (23,270 ) (4,826 ) Income taxes Total realized investment gain (loss) (net of tax) $24,219 $5,024 Total reclassifications for the period (net of tax) $45,915 $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 Louisiana for the three months ended June 30, 2017 and 2016 are as follows: Amounts reclassified Income Statement Location 2017 2016 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,934 $1,947 (a) Amortization of loss (1,332 ) (1,573 ) (a) Total amortization 602 374 (292 ) (144 ) Income taxes Total amortization (net of tax) 310 230 Total reclassifications for the period (net of tax) $310 $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 six months ended June 30, 2017 and 2016 are as follows: Amounts reclassified Income Statement Location 2017 2016 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $3,868 $3,894 (a) Amortization of loss (2,664 ) (3,142 ) (a) Total amortization 1,204 752 (524 ) (259 ) Income taxes Total amortization (net of tax) 680 493 Total reclassifications for the period (net of tax) $680 $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.
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, 2017 2016 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $409.9 179.5 $2.28 $567.3 178.8 $3.17 Average dilutive effect of: Stock options 0.2 — 0.2 — Other equity plans 0.5 (0.01 ) 0.5 (0.01 ) Diluted earnings per share $409.9 180.2 $2.27 $567.3 179.5 $3.16 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 2.5 million for the three months ended June 30, 2017 and approximately 4.1 million for the three months ended June 30, 2016 . For the Six Months Ended June 30, 2017 2016 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $492.5 179.4 $2.75 $797.3 178.7 $4.46 Average dilutive effect of: Stock options 0.2 — 0.1 — Other equity plans 0.4 (0.01 ) 0.4 (0.01 ) Diluted earnings per share $492.5 180.0 $2.74 $797.3 179.2 $4.45 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 3.7 million for the six months ended June 30, 2017 and approximately 5.1 million for the six months ended June 30, 2016 . 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, 2017 , Entergy Corporation issued 390,013 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, 2017 . Retained Earnings On July 28, 2017, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.87 per share, payable on September 1, 2017, to holders of record as of August 10, 2017. 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, 2017 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, April 1, 2017 $3,465 ($460,814 ) $467,561 $748 $10,960 Other comprehensive income (loss) before reclassifications 28,057 — 33,870 (748 ) 61,179 Amounts reclassified from accumulated other comprehensive income (loss) (8,108 ) 10,916 (22,174 ) — (19,366 ) Net other comprehensive income (loss) for the period 19,949 10,916 11,696 (748 ) 41,813 Ending balance, June 30, 2017 $23,414 ($449,898 ) $479,257 $— $52,773 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 six months ended June 30, 2017 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, January 1, 2017 $3,993 ($469,446 ) $429,734 $748 ($34,971 ) Other comprehensive income (loss) before reclassifications 60,665 — 73,742 (748 ) 133,659 Amounts reclassified from accumulated other comprehensive income (loss) (41,244 ) 19,548 (24,219 ) — (45,915 ) Net other comprehensive income (loss) for the period 19,421 19,548 49,523 (748 ) 87,744 Ending balance, June 30, 2017 $23,414 ($449,898 ) $479,257 $— $52,773 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 Louisiana for the three months ended June 30, 2017 and 2016: Pension and Other 2017 2016 (In Thousands) Beginning balance, April 1, ($48,812 ) ($56,675 ) Amounts reclassified from accumulated other (310 ) (230 ) Net other comprehensive income (loss) for the period (310 ) (230 ) Ending balance, June 30, ($49,122 ) ($56,905 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2017 and 2016: Pension and Other 2017 2016 (In Thousands) Beginning balance, January 1, ($48,442 ) ($56,412 ) Amounts reclassified from accumulated other (680 ) (493 ) Net other comprehensive income (loss) for the period (680 ) (493 ) Ending balance, June 30, ($49,122 ) ($56,905 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended June 30, 2017 and 2016 are as follows: Amounts reclassified Income Statement Location 2017 2016 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $12,695 $45,975 Competitive business operating revenues Interest rate swaps (219 ) 30 Miscellaneous - net Total realized gain (loss) on cash flow hedges 12,476 46,005 (4,368 ) (16,102 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $8,108 $29,903 Pension and other postretirement liabilities Amortization of prior-service credit $6,564 $7,355 (a) Amortization of loss (21,554 ) (15,177 ) (a) Settlement loss (1,765 ) — (a) Total amortization (16,755 ) (7,822 ) 5,839 2,779 Income taxes Total amortization (net of tax) ($10,916 ) ($5,043 ) Net unrealized investment gain (loss) Realized gain (loss) $43,479 $6,000 Interest and investment income (21,305 ) (2,939 ) Income taxes Total realized investment gain (loss) (net of tax) $22,174 $3,061 Total reclassifications for the period (net of tax) $19,366 $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 six months ended June 30, 2017 and 2016 are as follows: Amounts reclassified from AOCI Income Statement Location 2017 2016 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $63,922 $199,933 Competitive business operating revenues Interest rate swaps (469 ) (370 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 63,453 199,563 (22,209 ) (69,847 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $41,244 $129,716 Pension and other postretirement liabilities Amortization of prior-service credit $13,126 $14,710 (a) Amortization of loss (43,125 ) (30,352 ) (a) Settlement loss (1,765 ) — (a) Total amortization (31,764 ) (15,642 ) 12,216 3,037 Income taxes Total amortization (net of tax) ($19,548 ) ($12,605 ) Net unrealized investment gain (loss) Realized gain (loss) $47,489 $9,850 Interest and investment income (23,270 ) (4,826 ) Income taxes Total realized investment gain (loss) (net of tax) $24,219 $5,024 Total reclassifications for the period (net of tax) $45,915 $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 Louisiana for the three months ended June 30, 2017 and 2016 are as follows: Amounts reclassified Income Statement Location 2017 2016 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,934 $1,947 (a) Amortization of loss (1,332 ) (1,573 ) (a) Total amortization 602 374 (292 ) (144 ) Income taxes Total amortization (net of tax) 310 230 Total reclassifications for the period (net of tax) $310 $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 six months ended June 30, 2017 and 2016 are as follows: Amounts reclassified Income Statement Location 2017 2016 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $3,868 $3,894 (a) Amortization of loss (2,664 ) (3,142 ) (a) Total amortization 1,204 752 (524 ) (259 ) Income taxes Total amortization (net of tax) 680 493 Total reclassifications for the period (net of tax) $680 $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.

Revolving Credit Facilities, Li

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	6 Months Ended
	Jun. 30, 2017
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in August 2021. Entergy Corporation also has the ability to issue letters of credit against 50% of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the six months ended June 30, 2017 was 2.38% 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, 2017 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $225 $6 $3,269 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, 2017 , Entergy Corporation had $1.1 billion of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2017 was 1.38% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2017 Letters of Credit Outstanding as of June 30, 2017 Entergy Arkansas April 2018 $20 million (b) 2.48% $— $— Entergy Arkansas August 2021 $150 million (c) 2.48% $— $— Entergy Louisiana August 2021 $350 million (d) 2.48% $— $4.5 million Entergy Mississippi May 2018 $37.5 million (e) 2.73% $— $— Entergy Mississippi May 2018 $35 million (e) 2.73% $— $— Entergy Mississippi May 2018 $20 million (e) 2.73% $— $— Entergy Mississippi May 2018 $10 million (e) 2.73% $— $— Entergy New Orleans November 2018 $25 million (f) 2.70% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.73% $— $13.3 million (a) The interest rate is the rate as of June 30, 2017 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 to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2017 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2017 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $36.8 million Entergy Mississippi $40 million 0.70% $7.8 million Entergy New Orleans $15 million 0.75% $5.6 million Entergy Texas $50 million 0.70% $22.3 million (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. See Note 8 to the financial statements for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through October 31, 2017. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2017 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $14 Entergy Louisiana $450 $— Entergy Mississippi $175 $56 Entergy New Orleans $100 $— Entergy Texas $200 $39 System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $100 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 working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of June 30, 2017 , $71 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2017 was 2.44% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also has an uncommitted credit facility guaranteed by Entergy Corporation with a borrowing capacity of $85 million , which expires in January 2018. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides an additional funding source to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. As of June 30, 2017 , there were no cash borrowings outstanding under the credit facility. The rate as of June 30, 2017 that would most likely apply to outstanding borrowings under the facility was 2.72% . Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2017 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.39% $31.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.12% $15.5 Entergy Louisiana Waterford VIE May 2019 $85 2.38% $70.8 (c) System Energy VIE May 2019 $120 2.42% $103.2 (d) (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) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Arkansas VIE as of June 30, 2017 was $14.7 million . (c) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Louisiana Waterford VIE as of June 30, 2017 was $34.5 million . (d) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for System Energy VIE as of June 30, 2017 was $53.2 million . The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 2017 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 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 Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In May 2017, Entergy Arkansas issued $220 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 and June 2016. Entergy Arkansas used a portion of the proceeds from the May 2017 issuance for general corporate purposes and plans to use the remainder of the proceeds to pay, at maturity, its $54.7 million of 1.55% pollution control revenue refunding bonds due October 2017. (Entergy Louisiana) In May 2017, Entergy Louisiana issued $450 million of 3.12% collateral trust mortgage bonds due September 2027. Entergy Louisiana used the proceeds to finance the construction of the St. Charles Power Station, to pay, at maturity, its $45.3 million of Waterford Series collateral trust mortgage notes, and for general corporate purposes. In July 2017 the Entergy Louisiana River Bend nuclear fuel company variable interest entity paid, at maturity, its $75 million of 3.25% Series Q notes. In July 2017 the Entergy Louisiana Waterford nuclear fuel company variable interest entity paid, at maturity, its $25 million of 3.25% Series G notes. (System Energy) In February 2017 the System Energy nuclear fuel company variable interest entity paid, at maturity, its $50 million of 4.02% Series H notes. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2017 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,010,668 $15,239,655 Entergy Arkansas $3,064,261 $2,942,288 Entergy Louisiana $6,246,015 $6,484,470 Entergy Mississippi $1,121,356 $1,137,274 Entergy New Orleans $444,159 $467,094 Entergy Texas $1,471,091 $1,560,208 System Energy $551,296 $482,650 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2016 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,832,555 $14,815,535 Entergy Arkansas $2,829,785 $2,623,910 Entergy Louisiana $5,812,791 $5,929,488 Entergy Mississippi $1,120,916 $1,086,203 Entergy New Orleans $448,994 $455,459 Entergy Texas $1,508,407 $1,600,156 System Energy $551,132 $529,520 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein and are based on prices derived from inputs such as benchmark yields and reported trades.
Entergy Arkansas [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in August 2021. Entergy Corporation also has the ability to issue letters of credit against 50% of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the six months ended June 30, 2017 was 2.38% 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, 2017 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $225 $6 $3,269 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, 2017 , Entergy Corporation had $1.1 billion of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2017 was 1.38% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2017 Letters of Credit Outstanding as of June 30, 2017 Entergy Arkansas April 2018 $20 million (b) 2.48% $— $— Entergy Arkansas August 2021 $150 million (c) 2.48% $— $— Entergy Louisiana August 2021 $350 million (d) 2.48% $— $4.5 million Entergy Mississippi May 2018 $37.5 million (e) 2.73% $— $— Entergy Mississippi May 2018 $35 million (e) 2.73% $— $— Entergy Mississippi May 2018 $20 million (e) 2.73% $— $— Entergy Mississippi May 2018 $10 million (e) 2.73% $— $— Entergy New Orleans November 2018 $25 million (f) 2.70% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.73% $— $13.3 million (a) The interest rate is the rate as of June 30, 2017 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 to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2017 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2017 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $36.8 million Entergy Mississippi $40 million 0.70% $7.8 million Entergy New Orleans $15 million 0.75% $5.6 million Entergy Texas $50 million 0.70% $22.3 million (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. See Note 8 to the financial statements for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through October 31, 2017. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2017 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $14 Entergy Louisiana $450 $— Entergy Mississippi $175 $56 Entergy New Orleans $100 $— Entergy Texas $200 $39 System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $100 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 working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of June 30, 2017 , $71 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2017 was 2.44% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also has an uncommitted credit facility guaranteed by Entergy Corporation with a borrowing capacity of $85 million , which expires in January 2018. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides an additional funding source to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. As of June 30, 2017 , there were no cash borrowings outstanding under the credit facility. The rate as of June 30, 2017 that would most likely apply to outstanding borrowings under the facility was 2.72% . Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2017 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.39% $31.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.12% $15.5 Entergy Louisiana Waterford VIE May 2019 $85 2.38% $70.8 (c) System Energy VIE May 2019 $120 2.42% $103.2 (d) (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) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Arkansas VIE as of June 30, 2017 was $14.7 million . (c) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Louisiana Waterford VIE as of June 30, 2017 was $34.5 million . (d) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for System Energy VIE as of June 30, 2017 was $53.2 million . The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 2017 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 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 Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In May 2017, Entergy Arkansas issued $220 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 and June 2016. Entergy Arkansas used a portion of the proceeds from the May 2017 issuance for general corporate purposes and plans to use the remainder of the proceeds to pay, at maturity, its $54.7 million of 1.55% pollution control revenue refunding bonds due October 2017. (Entergy Louisiana) In May 2017, Entergy Louisiana issued $450 million of 3.12% collateral trust mortgage bonds due September 2027. Entergy Louisiana used the proceeds to finance the construction of the St. Charles Power Station, to pay, at maturity, its $45.3 million of Waterford Series collateral trust mortgage notes, and for general corporate purposes. In July 2017 the Entergy Louisiana River Bend nuclear fuel company variable interest entity paid, at maturity, its $75 million of 3.25% Series Q notes. In July 2017 the Entergy Louisiana Waterford nuclear fuel company variable interest entity paid, at maturity, its $25 million of 3.25% Series G notes. (System Energy) In February 2017 the System Energy nuclear fuel company variable interest entity paid, at maturity, its $50 million of 4.02% Series H notes. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2017 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,010,668 $15,239,655 Entergy Arkansas $3,064,261 $2,942,288 Entergy Louisiana $6,246,015 $6,484,470 Entergy Mississippi $1,121,356 $1,137,274 Entergy New Orleans $444,159 $467,094 Entergy Texas $1,471,091 $1,560,208 System Energy $551,296 $482,650 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2016 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,832,555 $14,815,535 Entergy Arkansas $2,829,785 $2,623,910 Entergy Louisiana $5,812,791 $5,929,488 Entergy Mississippi $1,120,916 $1,086,203 Entergy New Orleans $448,994 $455,459 Entergy Texas $1,508,407 $1,600,156 System Energy $551,132 $529,520 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein and are based on prices derived from inputs such as benchmark yields and reported trades.
Entergy Louisiana [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in August 2021. Entergy Corporation also has the ability to issue letters of credit against 50% of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the six months ended June 30, 2017 was 2.38% 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, 2017 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $225 $6 $3,269 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, 2017 , Entergy Corporation had $1.1 billion of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2017 was 1.38% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2017 Letters of Credit Outstanding as of June 30, 2017 Entergy Arkansas April 2018 $20 million (b) 2.48% $— $— Entergy Arkansas August 2021 $150 million (c) 2.48% $— $— Entergy Louisiana August 2021 $350 million (d) 2.48% $— $4.5 million Entergy Mississippi May 2018 $37.5 million (e) 2.73% $— $— Entergy Mississippi May 2018 $35 million (e) 2.73% $— $— Entergy Mississippi May 2018 $20 million (e) 2.73% $— $— Entergy Mississippi May 2018 $10 million (e) 2.73% $— $— Entergy New Orleans November 2018 $25 million (f) 2.70% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.73% $— $13.3 million (a) The interest rate is the rate as of June 30, 2017 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 to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2017 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2017 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $36.8 million Entergy Mississippi $40 million 0.70% $7.8 million Entergy New Orleans $15 million 0.75% $5.6 million Entergy Texas $50 million 0.70% $22.3 million (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. See Note 8 to the financial statements for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through October 31, 2017. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2017 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $14 Entergy Louisiana $450 $— Entergy Mississippi $175 $56 Entergy New Orleans $100 $— Entergy Texas $200 $39 System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $100 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 working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of June 30, 2017 , $71 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2017 was 2.44% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also has an uncommitted credit facility guaranteed by Entergy Corporation with a borrowing capacity of $85 million , which expires in January 2018. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides an additional funding source to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. As of June 30, 2017 , there were no cash borrowings outstanding under the credit facility. The rate as of June 30, 2017 that would most likely apply to outstanding borrowings under the facility was 2.72% . Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2017 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.39% $31.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.12% $15.5 Entergy Louisiana Waterford VIE May 2019 $85 2.38% $70.8 (c) System Energy VIE May 2019 $120 2.42% $103.2 (d) (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) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Arkansas VIE as of June 30, 2017 was $14.7 million . (c) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Louisiana Waterford VIE as of June 30, 2017 was $34.5 million . (d) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for System Energy VIE as of June 30, 2017 was $53.2 million . The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 2017 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 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 Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In May 2017, Entergy Arkansas issued $220 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 and June 2016. Entergy Arkansas used a portion of the proceeds from the May 2017 issuance for general corporate purposes and plans to use the remainder of the proceeds to pay, at maturity, its $54.7 million of 1.55% pollution control revenue refunding bonds due October 2017. (Entergy Louisiana) In May 2017, Entergy Louisiana issued $450 million of 3.12% collateral trust mortgage bonds due September 2027. Entergy Louisiana used the proceeds to finance the construction of the St. Charles Power Station, to pay, at maturity, its $45.3 million of Waterford Series collateral trust mortgage notes, and for general corporate purposes. In July 2017 the Entergy Louisiana River Bend nuclear fuel company variable interest entity paid, at maturity, its $75 million of 3.25% Series Q notes. In July 2017 the Entergy Louisiana Waterford nuclear fuel company variable interest entity paid, at maturity, its $25 million of 3.25% Series G notes. (System Energy) In February 2017 the System Energy nuclear fuel company variable interest entity paid, at maturity, its $50 million of 4.02% Series H notes. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2017 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,010,668 $15,239,655 Entergy Arkansas $3,064,261 $2,942,288 Entergy Louisiana $6,246,015 $6,484,470 Entergy Mississippi $1,121,356 $1,137,274 Entergy New Orleans $444,159 $467,094 Entergy Texas $1,471,091 $1,560,208 System Energy $551,296 $482,650 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2016 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,832,555 $14,815,535 Entergy Arkansas $2,829,785 $2,623,910 Entergy Louisiana $5,812,791 $5,929,488 Entergy Mississippi $1,120,916 $1,086,203 Entergy New Orleans $448,994 $455,459 Entergy Texas $1,508,407 $1,600,156 System Energy $551,132 $529,520 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein and are based on prices derived from inputs such as benchmark yields and reported trades.
Entergy Mississippi [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in August 2021. Entergy Corporation also has the ability to issue letters of credit against 50% of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the six months ended June 30, 2017 was 2.38% 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, 2017 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $225 $6 $3,269 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, 2017 , Entergy Corporation had $1.1 billion of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2017 was 1.38% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2017 Letters of Credit Outstanding as of June 30, 2017 Entergy Arkansas April 2018 $20 million (b) 2.48% $— $— Entergy Arkansas August 2021 $150 million (c) 2.48% $— $— Entergy Louisiana August 2021 $350 million (d) 2.48% $— $4.5 million Entergy Mississippi May 2018 $37.5 million (e) 2.73% $— $— Entergy Mississippi May 2018 $35 million (e) 2.73% $— $— Entergy Mississippi May 2018 $20 million (e) 2.73% $— $— Entergy Mississippi May 2018 $10 million (e) 2.73% $— $— Entergy New Orleans November 2018 $25 million (f) 2.70% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.73% $— $13.3 million (a) The interest rate is the rate as of June 30, 2017 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 to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2017 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2017 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $36.8 million Entergy Mississippi $40 million 0.70% $7.8 million Entergy New Orleans $15 million 0.75% $5.6 million Entergy Texas $50 million 0.70% $22.3 million (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. See Note 8 to the financial statements for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through October 31, 2017. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2017 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $14 Entergy Louisiana $450 $— Entergy Mississippi $175 $56 Entergy New Orleans $100 $— Entergy Texas $200 $39 System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $100 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 working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of June 30, 2017 , $71 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2017 was 2.44% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also has an uncommitted credit facility guaranteed by Entergy Corporation with a borrowing capacity of $85 million , which expires in January 2018. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides an additional funding source to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. As of June 30, 2017 , there were no cash borrowings outstanding under the credit facility. The rate as of June 30, 2017 that would most likely apply to outstanding borrowings under the facility was 2.72% . Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2017 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.39% $31.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.12% $15.5 Entergy Louisiana Waterford VIE May 2019 $85 2.38% $70.8 (c) System Energy VIE May 2019 $120 2.42% $103.2 (d) (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) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Arkansas VIE as of June 30, 2017 was $14.7 million . (c) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Louisiana Waterford VIE as of June 30, 2017 was $34.5 million . (d) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for System Energy VIE as of June 30, 2017 was $53.2 million . The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 2017 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 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 Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In May 2017, Entergy Arkansas issued $220 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 and June 2016. Entergy Arkansas used a portion of the proceeds from the May 2017 issuance for general corporate purposes and plans to use the remainder of the proceeds to pay, at maturity, its $54.7 million of 1.55% pollution control revenue refunding bonds due October 2017. (Entergy Louisiana) In May 2017, Entergy Louisiana issued $450 million of 3.12% collateral trust mortgage bonds due September 2027. Entergy Louisiana used the proceeds to finance the construction of the St. Charles Power Station, to pay, at maturity, its $45.3 million of Waterford Series collateral trust mortgage notes, and for general corporate purposes. In July 2017 the Entergy Louisiana River Bend nuclear fuel company variable interest entity paid, at maturity, its $75 million of 3.25% Series Q notes. In July 2017 the Entergy Louisiana Waterford nuclear fuel company variable interest entity paid, at maturity, its $25 million of 3.25% Series G notes. (System Energy) In February 2017 the System Energy nuclear fuel company variable interest entity paid, at maturity, its $50 million of 4.02% Series H notes. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2017 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,010,668 $15,239,655 Entergy Arkansas $3,064,261 $2,942,288 Entergy Louisiana $6,246,015 $6,484,470 Entergy Mississippi $1,121,356 $1,137,274 Entergy New Orleans $444,159 $467,094 Entergy Texas $1,471,091 $1,560,208 System Energy $551,296 $482,650 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2016 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,832,555 $14,815,535 Entergy Arkansas $2,829,785 $2,623,910 Entergy Louisiana $5,812,791 $5,929,488 Entergy Mississippi $1,120,916 $1,086,203 Entergy New Orleans $448,994 $455,459 Entergy Texas $1,508,407 $1,600,156 System Energy $551,132 $529,520 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein and are based on prices derived from inputs such as benchmark yields and reported trades.
Entergy New Orleans [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in August 2021. Entergy Corporation also has the ability to issue letters of credit against 50% of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the six months ended June 30, 2017 was 2.38% 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, 2017 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $225 $6 $3,269 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, 2017 , Entergy Corporation had $1.1 billion of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2017 was 1.38% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2017 Letters of Credit Outstanding as of June 30, 2017 Entergy Arkansas April 2018 $20 million (b) 2.48% $— $— Entergy Arkansas August 2021 $150 million (c) 2.48% $— $— Entergy Louisiana August 2021 $350 million (d) 2.48% $— $4.5 million Entergy Mississippi May 2018 $37.5 million (e) 2.73% $— $— Entergy Mississippi May 2018 $35 million (e) 2.73% $— $— Entergy Mississippi May 2018 $20 million (e) 2.73% $— $— Entergy Mississippi May 2018 $10 million (e) 2.73% $— $— Entergy New Orleans November 2018 $25 million (f) 2.70% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.73% $— $13.3 million (a) The interest rate is the rate as of June 30, 2017 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 to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2017 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2017 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $36.8 million Entergy Mississippi $40 million 0.70% $7.8 million Entergy New Orleans $15 million 0.75% $5.6 million Entergy Texas $50 million 0.70% $22.3 million (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. See Note 8 to the financial statements for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through October 31, 2017. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2017 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $14 Entergy Louisiana $450 $— Entergy Mississippi $175 $56 Entergy New Orleans $100 $— Entergy Texas $200 $39 System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $100 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 working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of June 30, 2017 , $71 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2017 was 2.44% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also has an uncommitted credit facility guaranteed by Entergy Corporation with a borrowing capacity of $85 million , which expires in January 2018. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides an additional funding source to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. As of June 30, 2017 , there were no cash borrowings outstanding under the credit facility. The rate as of June 30, 2017 that would most likely apply to outstanding borrowings under the facility was 2.72% . Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2017 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.39% $31.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.12% $15.5 Entergy Louisiana Waterford VIE May 2019 $85 2.38% $70.8 (c) System Energy VIE May 2019 $120 2.42% $103.2 (d) (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) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Arkansas VIE as of June 30, 2017 was $14.7 million . (c) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Louisiana Waterford VIE as of June 30, 2017 was $34.5 million . (d) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for System Energy VIE as of June 30, 2017 was $53.2 million . The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 2017 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 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 Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In May 2017, Entergy Arkansas issued $220 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 and June 2016. Entergy Arkansas used a portion of the proceeds from the May 2017 issuance for general corporate purposes and plans to use the remainder of the proceeds to pay, at maturity, its $54.7 million of 1.55% pollution control revenue refunding bonds due October 2017. (Entergy Louisiana) In May 2017, Entergy Louisiana issued $450 million of 3.12% collateral trust mortgage bonds due September 2027. Entergy Louisiana used the proceeds to finance the construction of the St. Charles Power Station, to pay, at maturity, its $45.3 million of Waterford Series collateral trust mortgage notes, and for general corporate purposes. In July 2017 the Entergy Louisiana River Bend nuclear fuel company variable interest entity paid, at maturity, its $75 million of 3.25% Series Q notes. In July 2017 the Entergy Louisiana Waterford nuclear fuel company variable interest entity paid, at maturity, its $25 million of 3.25% Series G notes. (System Energy) In February 2017 the System Energy nuclear fuel company variable interest entity paid, at maturity, its $50 million of 4.02% Series H notes. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2017 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,010,668 $15,239,655 Entergy Arkansas $3,064,261 $2,942,288 Entergy Louisiana $6,246,015 $6,484,470 Entergy Mississippi $1,121,356 $1,137,274 Entergy New Orleans $444,159 $467,094 Entergy Texas $1,471,091 $1,560,208 System Energy $551,296 $482,650 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2016 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,832,555 $14,815,535 Entergy Arkansas $2,829,785 $2,623,910 Entergy Louisiana $5,812,791 $5,929,488 Entergy Mississippi $1,120,916 $1,086,203 Entergy New Orleans $448,994 $455,459 Entergy Texas $1,508,407 $1,600,156 System Energy $551,132 $529,520 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein and are based on prices derived from inputs such as benchmark yields and reported trades.
Entergy Texas [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in August 2021. Entergy Corporation also has the ability to issue letters of credit against 50% of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the six months ended June 30, 2017 was 2.38% 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, 2017 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $225 $6 $3,269 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, 2017 , Entergy Corporation had $1.1 billion of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2017 was 1.38% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2017 Letters of Credit Outstanding as of June 30, 2017 Entergy Arkansas April 2018 $20 million (b) 2.48% $— $— Entergy Arkansas August 2021 $150 million (c) 2.48% $— $— Entergy Louisiana August 2021 $350 million (d) 2.48% $— $4.5 million Entergy Mississippi May 2018 $37.5 million (e) 2.73% $— $— Entergy Mississippi May 2018 $35 million (e) 2.73% $— $— Entergy Mississippi May 2018 $20 million (e) 2.73% $— $— Entergy Mississippi May 2018 $10 million (e) 2.73% $— $— Entergy New Orleans November 2018 $25 million (f) 2.70% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.73% $— $13.3 million (a) The interest rate is the rate as of June 30, 2017 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 to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2017 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2017 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $36.8 million Entergy Mississippi $40 million 0.70% $7.8 million Entergy New Orleans $15 million 0.75% $5.6 million Entergy Texas $50 million 0.70% $22.3 million (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. See Note 8 to the financial statements for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through October 31, 2017. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2017 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $14 Entergy Louisiana $450 $— Entergy Mississippi $175 $56 Entergy New Orleans $100 $— Entergy Texas $200 $39 System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $100 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 working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of June 30, 2017 , $71 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2017 was 2.44% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also has an uncommitted credit facility guaranteed by Entergy Corporation with a borrowing capacity of $85 million , which expires in January 2018. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides an additional funding source to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. As of June 30, 2017 , there were no cash borrowings outstanding under the credit facility. The rate as of June 30, 2017 that would most likely apply to outstanding borrowings under the facility was 2.72% . Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2017 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.39% $31.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.12% $15.5 Entergy Louisiana Waterford VIE May 2019 $85 2.38% $70.8 (c) System Energy VIE May 2019 $120 2.42% $103.2 (d) (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) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Arkansas VIE as of June 30, 2017 was $14.7 million . (c) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Louisiana Waterford VIE as of June 30, 2017 was $34.5 million . (d) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for System Energy VIE as of June 30, 2017 was $53.2 million . The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 2017 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 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 Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In May 2017, Entergy Arkansas issued $220 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 and June 2016. Entergy Arkansas used a portion of the proceeds from the May 2017 issuance for general corporate purposes and plans to use the remainder of the proceeds to pay, at maturity, its $54.7 million of 1.55% pollution control revenue refunding bonds due October 2017. (Entergy Louisiana) In May 2017, Entergy Louisiana issued $450 million of 3.12% collateral trust mortgage bonds due September 2027. Entergy Louisiana used the proceeds to finance the construction of the St. Charles Power Station, to pay, at maturity, its $45.3 million of Waterford Series collateral trust mortgage notes, and for general corporate purposes. In July 2017 the Entergy Louisiana River Bend nuclear fuel company variable interest entity paid, at maturity, its $75 million of 3.25% Series Q notes. In July 2017 the Entergy Louisiana Waterford nuclear fuel company variable interest entity paid, at maturity, its $25 million of 3.25% Series G notes. (System Energy) In February 2017 the System Energy nuclear fuel company variable interest entity paid, at maturity, its $50 million of 4.02% Series H notes. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2017 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,010,668 $15,239,655 Entergy Arkansas $3,064,261 $2,942,288 Entergy Louisiana $6,246,015 $6,484,470 Entergy Mississippi $1,121,356 $1,137,274 Entergy New Orleans $444,159 $467,094 Entergy Texas $1,471,091 $1,560,208 System Energy $551,296 $482,650 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2016 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,832,555 $14,815,535 Entergy Arkansas $2,829,785 $2,623,910 Entergy Louisiana $5,812,791 $5,929,488 Entergy Mississippi $1,120,916 $1,086,203 Entergy New Orleans $448,994 $455,459 Entergy Texas $1,508,407 $1,600,156 System Energy $551,132 $529,520 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein and are based on prices derived from inputs such as benchmark yields and reported trades.
System Energy [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in August 2021. Entergy Corporation also has the ability to issue letters of credit against 50% of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the six months ended June 30, 2017 was 2.38% 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, 2017 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $225 $6 $3,269 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, 2017 , Entergy Corporation had $1.1 billion of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2017 was 1.38% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2017 Letters of Credit Outstanding as of June 30, 2017 Entergy Arkansas April 2018 $20 million (b) 2.48% $— $— Entergy Arkansas August 2021 $150 million (c) 2.48% $— $— Entergy Louisiana August 2021 $350 million (d) 2.48% $— $4.5 million Entergy Mississippi May 2018 $37.5 million (e) 2.73% $— $— Entergy Mississippi May 2018 $35 million (e) 2.73% $— $— Entergy Mississippi May 2018 $20 million (e) 2.73% $— $— Entergy Mississippi May 2018 $10 million (e) 2.73% $— $— Entergy New Orleans November 2018 $25 million (f) 2.70% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.73% $— $13.3 million (a) The interest rate is the rate as of June 30, 2017 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 to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2017 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2017 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $36.8 million Entergy Mississippi $40 million 0.70% $7.8 million Entergy New Orleans $15 million 0.75% $5.6 million Entergy Texas $50 million 0.70% $22.3 million (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. See Note 8 to the financial statements for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through October 31, 2017. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2017 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $14 Entergy Louisiana $450 $— Entergy Mississippi $175 $56 Entergy New Orleans $100 $— Entergy Texas $200 $39 System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facilities Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $100 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 working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of June 30, 2017 , $71 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2017 was 2.44% on the drawn portion of the facility. Entergy Nuclear Vermont Yankee also has an uncommitted credit facility guaranteed by Entergy Corporation with a borrowing capacity of $85 million , which expires in January 2018. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides an additional funding source to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. As of June 30, 2017 , there were no cash borrowings outstanding under the credit facility. The rate as of June 30, 2017 that would most likely apply to outstanding borrowings under the facility was 2.72% . Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2017 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.39% $31.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.12% $15.5 Entergy Louisiana Waterford VIE May 2019 $85 2.38% $70.8 (c) System Energy VIE May 2019 $120 2.42% $103.2 (d) (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) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Arkansas VIE as of June 30, 2017 was $14.7 million . (c) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Louisiana Waterford VIE as of June 30, 2017 was $34.5 million . (d) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for System Energy VIE as of June 30, 2017 was $53.2 million . The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of June 30, 2017 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 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 Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In May 2017, Entergy Arkansas issued $220 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 and June 2016. Entergy Arkansas used a portion of the proceeds from the May 2017 issuance for general corporate purposes and plans to use the remainder of the proceeds to pay, at maturity, its $54.7 million of 1.55% pollution control revenue refunding bonds due October 2017. (Entergy Louisiana) In May 2017, Entergy Louisiana issued $450 million of 3.12% collateral trust mortgage bonds due September 2027. Entergy Louisiana used the proceeds to finance the construction of the St. Charles Power Station, to pay, at maturity, its $45.3 million of Waterford Series collateral trust mortgage notes, and for general corporate purposes. In July 2017 the Entergy Louisiana River Bend nuclear fuel company variable interest entity paid, at maturity, its $75 million of 3.25% Series Q notes. In July 2017 the Entergy Louisiana Waterford nuclear fuel company variable interest entity paid, at maturity, its $25 million of 3.25% Series G notes. (System Energy) In February 2017 the System Energy nuclear fuel company variable interest entity paid, at maturity, its $50 million of 4.02% Series H notes. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2017 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,010,668 $15,239,655 Entergy Arkansas $3,064,261 $2,942,288 Entergy Louisiana $6,246,015 $6,484,470 Entergy Mississippi $1,121,356 $1,137,274 Entergy New Orleans $444,159 $467,094 Entergy Texas $1,471,091 $1,560,208 System Energy $551,296 $482,650 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2016 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,832,555 $14,815,535 Entergy Arkansas $2,829,785 $2,623,910 Entergy Louisiana $5,812,791 $5,929,488 Entergy Mississippi $1,120,916 $1,086,203 Entergy New Orleans $448,994 $455,459 Entergy Texas $1,508,407 $1,600,156 System Energy $551,132 $529,520 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2017
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. Effective January 1, 2017, Entergy adopted ASU 2016-09, which permits the election of an accounting policy change to the method of recognizing forfeitures of stock-based compensation. Previously, Entergy recorded an estimate of the number of forfeitures expected to occur each period. Entergy elected to change this policy to account for forfeitures when they occur. This accounting change was applied retrospectively, but did not result in an adjustment to retained earnings as of January 1, 2017. Stock Options Entergy granted options on 791,900 shares of its common stock under the 2015 Equity Ownership Plan during the first quarter 2017 with a weighted-average fair value of $6.54 per option. As of June 30, 2017 , there were options on 6,162,359 shares of common stock outstanding with a weighted-average exercise price of $81.65 . 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, 2017 . Because Entergy’s stock price at June 30, 2017 was less than the weighted average exercise price, the aggregate intrinsic value of the stock options outstanding as of June 30, 2017 was zero. The intrinsic value of all “in the money” stock options was $21.5 million as of June 30, 2017 . The following table includes financial information for outstanding stock options for the three months ended June 30, 2017 and 2016 : 2017 2016 (In Millions) Compensation expense included in Entergy’s net income $1.1 $1.1 Tax benefit recognized in Entergy’s net income $0.4 $0.4 Compensation cost capitalized as part of fixed assets and inventory $0.2 $0.2 The following table includes financial information for outstanding stock options for the six months ended June 30, 2017 and 2016 : 2017 2016 (In Millions) Compensation expense included in Entergy’s net income $2.2 $2.2 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 2017 the Board approved and Entergy granted 379,850 restricted stock awards and 220,450 long-term incentive awards under the 2015 Equity Ownership Plan. The restricted stock awards were made effective as of January 26, 2017 and were valued at $70.53 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 26, 2017 and were valued at $71.40 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, 2017 and 2016 : 2017 2016 (In Millions) Compensation expense included in Entergy’s net income $8.2 $8.5 Tax benefit recognized in Entergy’s net income $3.2 $3.3 Compensation cost capitalized as part of fixed assets and inventory $2.2 $1.9 The following table includes financial information for other outstanding equity awards for the six months ended June 30, 2017 and 2016 : 2017 2016 (In Millions) Compensation expense included in Entergy’s net income $16.4 $16.9 Tax benefit recognized in Entergy’s net income $6.3 $6.5 Compensation cost capitalized as part of fixed assets and inventory $4.2 $3.7

Retirement And Other Postretire

Retirement And Other Postretirement Benefits	6 Months Ended
	Jun. 30, 2017
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 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $33,410 $35,811 Interest cost on projected benefit obligation 65,206 65,403 Expected return on assets (102,056 ) (97,366 ) Amortization of prior service cost 65 270 Amortization of loss 56,930 48,824 Net pension costs $53,555 $52,942 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $66,820 $71,622 Interest cost on projected benefit obligation 130,412 130,806 Expected return on assets (204,112 ) (194,732 ) Amortization of prior service cost 130 540 Amortization of loss 113,860 97,648 Net pension costs $107,110 $105,884 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,180 $13,850 $2,944 $1,250 $2,728 $3,072 Interest cost on projects benefit obligation 25,888 29,618 7,464 3,582 6,784 6,182 Expected return on assets (40,854 ) (46,034 ) (12,262 ) (5,600 ) (12,360 ) (9,326 ) Amortization of loss 23,280 24,708 6,106 3,316 4,620 5,928 Net pension cost $18,494 $22,142 $4,252 $2,548 $1,772 $5,856 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 Non-Qualified Net Pension Cost Entergy recognized $8.5 million and $4.3 million in pension cost for its non-qualified pension plans in the second quarters of 2017 and 2016 , respectively. Reflected in the pension cost for non-qualified pension plans in the second quarter 2017 is a $4 million settlement charge recognized in June 2017 related to the payment of lump sum benefits out of this plan. Entergy recognized $13.1 million and $8.5 million in pensions costs for its non-qualified pension plans for the six months ended June 30, 2017 and 2016, respectively. Reflected in the pension cost for non-qualified pension plans for the six months ended June 30, 2017 is a $4 million settlement charge recognized in June 2017 related to the payment of lump sum benefits out of this plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the second quarters of 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $267 $47 $63 $18 $126 2016 $106 $59 $59 $16 $127 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $372 $96 $127 $36 $253 2016 $212 $118 $118 $32 $254 Reflected in Entergy Arkansas’s non-qualified pension costs in the second quarter 2017 and for the six months ended June 30, 2017 is $163 thousand in settlement charges recognized in June 2017 related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the second quarters of 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $6,729 $8,073 Interest cost on accumulated postretirement benefit obligation (APBO) 13,960 14,083 Expected return on assets (9,408 ) (10,455 ) Amortization of prior service credit (10,356 ) (11,373 ) Amortization of loss 5,476 4,554 Net other postretirement benefit cost $6,401 $4,882 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $13,458 $16,146 Interest cost on accumulated postretirement benefit obligation (APBO) 27,920 28,166 Expected return on assets (18,816 ) (20,910 ) Amortization of prior service credit (20,712 ) (22,746 ) Amortization of loss 10,952 9,108 Net other postretirement benefit cost $12,802 $9,764 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the second quarters of 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,726 $3,186 $580 $284 $744 $640 Interest cost on APBO 4,510 6,050 1,380 938 2,248 1,118 Expected return on assets (7,918 ) — (2,400 ) (2,318 ) (4,360 ) (1,434 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of loss 2,230 930 838 210 1,652 780 Net other postretirement benefit cost ($2,008 ) $6,298 ($514 ) ($1,258 ) ($874 ) $348 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 ) 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 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($89 ) $6,564 Amortization of loss (18,450 ) (2,202 ) (902 ) (21,554 ) Settlement loss — — (1,765 ) (1,765 ) ($18,515 ) $4,516 ($2,756 ) ($16,755 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 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 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, 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($130 ) $13,435 ($179 ) $13,126 Amortization of loss (36,899 ) (4,404 ) (1,822 ) (43,125 ) Settlement loss — — (1,765 ) (1,765 ) ($37,029 ) $9,031 ($3,766 ) ($31,764 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of loss (1,730 ) (930 ) (4 ) (2,664 ) ($1,730 ) $2,938 ($4 ) $1,204 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 Employer Contributions Based on current assumptions, Entergy expects to contribute $409.9 million to its qualified pension plans in 2017. As of June 30, 2017 , Entergy had contributed $176 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 2017 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2017 pension contributions $79,495 $87,923 $19,146 $9,920 $17,064 $18,180 Pension contributions made through June 2017 $34,507 $37,519 $8,251 $4,361 $7,227 $8,182 Remaining estimated pension contributions to be made in 2017 $44,988 $50,404 $10,895 $5,559 $9,837 $9,998
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 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $33,410 $35,811 Interest cost on projected benefit obligation 65,206 65,403 Expected return on assets (102,056 ) (97,366 ) Amortization of prior service cost 65 270 Amortization of loss 56,930 48,824 Net pension costs $53,555 $52,942 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $66,820 $71,622 Interest cost on projected benefit obligation 130,412 130,806 Expected return on assets (204,112 ) (194,732 ) Amortization of prior service cost 130 540 Amortization of loss 113,860 97,648 Net pension costs $107,110 $105,884 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,180 $13,850 $2,944 $1,250 $2,728 $3,072 Interest cost on projects benefit obligation 25,888 29,618 7,464 3,582 6,784 6,182 Expected return on assets (40,854 ) (46,034 ) (12,262 ) (5,600 ) (12,360 ) (9,326 ) Amortization of loss 23,280 24,708 6,106 3,316 4,620 5,928 Net pension cost $18,494 $22,142 $4,252 $2,548 $1,772 $5,856 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 Non-Qualified Net Pension Cost Entergy recognized $8.5 million and $4.3 million in pension cost for its non-qualified pension plans in the second quarters of 2017 and 2016 , respectively. Reflected in the pension cost for non-qualified pension plans in the second quarter 2017 is a $4 million settlement charge recognized in June 2017 related to the payment of lump sum benefits out of this plan. Entergy recognized $13.1 million and $8.5 million in pensions costs for its non-qualified pension plans for the six months ended June 30, 2017 and 2016, respectively. Reflected in the pension cost for non-qualified pension plans for the six months ended June 30, 2017 is a $4 million settlement charge recognized in June 2017 related to the payment of lump sum benefits out of this plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the second quarters of 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $267 $47 $63 $18 $126 2016 $106 $59 $59 $16 $127 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $372 $96 $127 $36 $253 2016 $212 $118 $118 $32 $254 Reflected in Entergy Arkansas’s non-qualified pension costs in the second quarter 2017 and for the six months ended June 30, 2017 is $163 thousand in settlement charges recognized in June 2017 related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the second quarters of 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $6,729 $8,073 Interest cost on accumulated postretirement benefit obligation (APBO) 13,960 14,083 Expected return on assets (9,408 ) (10,455 ) Amortization of prior service credit (10,356 ) (11,373 ) Amortization of loss 5,476 4,554 Net other postretirement benefit cost $6,401 $4,882 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $13,458 $16,146 Interest cost on accumulated postretirement benefit obligation (APBO) 27,920 28,166 Expected return on assets (18,816 ) (20,910 ) Amortization of prior service credit (20,712 ) (22,746 ) Amortization of loss 10,952 9,108 Net other postretirement benefit cost $12,802 $9,764 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the second quarters of 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,726 $3,186 $580 $284 $744 $640 Interest cost on APBO 4,510 6,050 1,380 938 2,248 1,118 Expected return on assets (7,918 ) — (2,400 ) (2,318 ) (4,360 ) (1,434 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of loss 2,230 930 838 210 1,652 780 Net other postretirement benefit cost ($2,008 ) $6,298 ($514 ) ($1,258 ) ($874 ) $348 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 ) 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 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($89 ) $6,564 Amortization of loss (18,450 ) (2,202 ) (902 ) (21,554 ) Settlement loss — — (1,765 ) (1,765 ) ($18,515 ) $4,516 ($2,756 ) ($16,755 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 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 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, 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($130 ) $13,435 ($179 ) $13,126 Amortization of loss (36,899 ) (4,404 ) (1,822 ) (43,125 ) Settlement loss — — (1,765 ) (1,765 ) ($37,029 ) $9,031 ($3,766 ) ($31,764 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of loss (1,730 ) (930 ) (4 ) (2,664 ) ($1,730 ) $2,938 ($4 ) $1,204 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 Employer Contributions Based on current assumptions, Entergy expects to contribute $409.9 million to its qualified pension plans in 2017. As of June 30, 2017 , Entergy had contributed $176 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 2017 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2017 pension contributions $79,495 $87,923 $19,146 $9,920 $17,064 $18,180 Pension contributions made through June 2017 $34,507 $37,519 $8,251 $4,361 $7,227 $8,182 Remaining estimated pension contributions to be made in 2017 $44,988 $50,404 $10,895 $5,559 $9,837 $9,998
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 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $33,410 $35,811 Interest cost on projected benefit obligation 65,206 65,403 Expected return on assets (102,056 ) (97,366 ) Amortization of prior service cost 65 270 Amortization of loss 56,930 48,824 Net pension costs $53,555 $52,942 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $66,820 $71,622 Interest cost on projected benefit obligation 130,412 130,806 Expected return on assets (204,112 ) (194,732 ) Amortization of prior service cost 130 540 Amortization of loss 113,860 97,648 Net pension costs $107,110 $105,884 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,180 $13,850 $2,944 $1,250 $2,728 $3,072 Interest cost on projects benefit obligation 25,888 29,618 7,464 3,582 6,784 6,182 Expected return on assets (40,854 ) (46,034 ) (12,262 ) (5,600 ) (12,360 ) (9,326 ) Amortization of loss 23,280 24,708 6,106 3,316 4,620 5,928 Net pension cost $18,494 $22,142 $4,252 $2,548 $1,772 $5,856 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 Non-Qualified Net Pension Cost Entergy recognized $8.5 million and $4.3 million in pension cost for its non-qualified pension plans in the second quarters of 2017 and 2016 , respectively. Reflected in the pension cost for non-qualified pension plans in the second quarter 2017 is a $4 million settlement charge recognized in June 2017 related to the payment of lump sum benefits out of this plan. Entergy recognized $13.1 million and $8.5 million in pensions costs for its non-qualified pension plans for the six months ended June 30, 2017 and 2016, respectively. Reflected in the pension cost for non-qualified pension plans for the six months ended June 30, 2017 is a $4 million settlement charge recognized in June 2017 related to the payment of lump sum benefits out of this plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the second quarters of 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $267 $47 $63 $18 $126 2016 $106 $59 $59 $16 $127 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $372 $96 $127 $36 $253 2016 $212 $118 $118 $32 $254 Reflected in Entergy Arkansas’s non-qualified pension costs in the second quarter 2017 and for the six months ended June 30, 2017 is $163 thousand in settlement charges recognized in June 2017 related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the second quarters of 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $6,729 $8,073 Interest cost on accumulated postretirement benefit obligation (APBO) 13,960 14,083 Expected return on assets (9,408 ) (10,455 ) Amortization of prior service credit (10,356 ) (11,373 ) Amortization of loss 5,476 4,554 Net other postretirement benefit cost $6,401 $4,882 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $13,458 $16,146 Interest cost on accumulated postretirement benefit obligation (APBO) 27,920 28,166 Expected return on assets (18,816 ) (20,910 ) Amortization of prior service credit (20,712 ) (22,746 ) Amortization of loss 10,952 9,108 Net other postretirement benefit cost $12,802 $9,764 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the second quarters of 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,726 $3,186 $580 $284 $744 $640 Interest cost on APBO 4,510 6,050 1,380 938 2,248 1,118 Expected return on assets (7,918 ) — (2,400 ) (2,318 ) (4,360 ) (1,434 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of loss 2,230 930 838 210 1,652 780 Net other postretirement benefit cost ($2,008 ) $6,298 ($514 ) ($1,258 ) ($874 ) $348 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 ) 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 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($89 ) $6,564 Amortization of loss (18,450 ) (2,202 ) (902 ) (21,554 ) Settlement loss — — (1,765 ) (1,765 ) ($18,515 ) $4,516 ($2,756 ) ($16,755 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 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 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, 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($130 ) $13,435 ($179 ) $13,126 Amortization of loss (36,899 ) (4,404 ) (1,822 ) (43,125 ) Settlement loss — — (1,765 ) (1,765 ) ($37,029 ) $9,031 ($3,766 ) ($31,764 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of loss (1,730 ) (930 ) (4 ) (2,664 ) ($1,730 ) $2,938 ($4 ) $1,204 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 Employer Contributions Based on current assumptions, Entergy expects to contribute $409.9 million to its qualified pension plans in 2017. As of June 30, 2017 , Entergy had contributed $176 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 2017 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2017 pension contributions $79,495 $87,923 $19,146 $9,920 $17,064 $18,180 Pension contributions made through June 2017 $34,507 $37,519 $8,251 $4,361 $7,227 $8,182 Remaining estimated pension contributions to be made in 2017 $44,988 $50,404 $10,895 $5,559 $9,837 $9,998
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 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $33,410 $35,811 Interest cost on projected benefit obligation 65,206 65,403 Expected return on assets (102,056 ) (97,366 ) Amortization of prior service cost 65 270 Amortization of loss 56,930 48,824 Net pension costs $53,555 $52,942 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $66,820 $71,622 Interest cost on projected benefit obligation 130,412 130,806 Expected return on assets (204,112 ) (194,732 ) Amortization of prior service cost 130 540 Amortization of loss 113,860 97,648 Net pension costs $107,110 $105,884 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,180 $13,850 $2,944 $1,250 $2,728 $3,072 Interest cost on projects benefit obligation 25,888 29,618 7,464 3,582 6,784 6,182 Expected return on assets (40,854 ) (46,034 ) (12,262 ) (5,600 ) (12,360 ) (9,326 ) Amortization of loss 23,280 24,708 6,106 3,316 4,620 5,928 Net pension cost $18,494 $22,142 $4,252 $2,548 $1,772 $5,856 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 Non-Qualified Net Pension Cost Entergy recognized $8.5 million and $4.3 million in pension cost for its non-qualified pension plans in the second quarters of 2017 and 2016 , respectively. Reflected in the pension cost for non-qualified pension plans in the second quarter 2017 is a $4 million settlement charge recognized in June 2017 related to the payment of lump sum benefits out of this plan. Entergy recognized $13.1 million and $8.5 million in pensions costs for its non-qualified pension plans for the six months ended June 30, 2017 and 2016, respectively. Reflected in the pension cost for non-qualified pension plans for the six months ended June 30, 2017 is a $4 million settlement charge recognized in June 2017 related to the payment of lump sum benefits out of this plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the second quarters of 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $267 $47 $63 $18 $126 2016 $106 $59 $59 $16 $127 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $372 $96 $127 $36 $253 2016 $212 $118 $118 $32 $254 Reflected in Entergy Arkansas’s non-qualified pension costs in the second quarter 2017 and for the six months ended June 30, 2017 is $163 thousand in settlement charges recognized in June 2017 related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the second quarters of 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $6,729 $8,073 Interest cost on accumulated postretirement benefit obligation (APBO) 13,960 14,083 Expected return on assets (9,408 ) (10,455 ) Amortization of prior service credit (10,356 ) (11,373 ) Amortization of loss 5,476 4,554 Net other postretirement benefit cost $6,401 $4,882 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $13,458 $16,146 Interest cost on accumulated postretirement benefit obligation (APBO) 27,920 28,166 Expected return on assets (18,816 ) (20,910 ) Amortization of prior service credit (20,712 ) (22,746 ) Amortization of loss 10,952 9,108 Net other postretirement benefit cost $12,802 $9,764 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the second quarters of 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,726 $3,186 $580 $284 $744 $640 Interest cost on APBO 4,510 6,050 1,380 938 2,248 1,118 Expected return on assets (7,918 ) — (2,400 ) (2,318 ) (4,360 ) (1,434 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of loss 2,230 930 838 210 1,652 780 Net other postretirement benefit cost ($2,008 ) $6,298 ($514 ) ($1,258 ) ($874 ) $348 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 ) 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 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($89 ) $6,564 Amortization of loss (18,450 ) (2,202 ) (902 ) (21,554 ) Settlement loss — — (1,765 ) (1,765 ) ($18,515 ) $4,516 ($2,756 ) ($16,755 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 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 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, 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($130 ) $13,435 ($179 ) $13,126 Amortization of loss (36,899 ) (4,404 ) (1,822 ) (43,125 ) Settlement loss — — (1,765 ) (1,765 ) ($37,029 ) $9,031 ($3,766 ) ($31,764 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of loss (1,730 ) (930 ) (4 ) (2,664 ) ($1,730 ) $2,938 ($4 ) $1,204 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 Employer Contributions Based on current assumptions, Entergy expects to contribute $409.9 million to its qualified pension plans in 2017. As of June 30, 2017 , Entergy had contributed $176 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 2017 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2017 pension contributions $79,495 $87,923 $19,146 $9,920 $17,064 $18,180 Pension contributions made through June 2017 $34,507 $37,519 $8,251 $4,361 $7,227 $8,182 Remaining estimated pension contributions to be made in 2017 $44,988 $50,404 $10,895 $5,559 $9,837 $9,998
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 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $33,410 $35,811 Interest cost on projected benefit obligation 65,206 65,403 Expected return on assets (102,056 ) (97,366 ) Amortization of prior service cost 65 270 Amortization of loss 56,930 48,824 Net pension costs $53,555 $52,942 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $66,820 $71,622 Interest cost on projected benefit obligation 130,412 130,806 Expected return on assets (204,112 ) (194,732 ) Amortization of prior service cost 130 540 Amortization of loss 113,860 97,648 Net pension costs $107,110 $105,884 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,180 $13,850 $2,944 $1,250 $2,728 $3,072 Interest cost on projects benefit obligation 25,888 29,618 7,464 3,582 6,784 6,182 Expected return on assets (40,854 ) (46,034 ) (12,262 ) (5,600 ) (12,360 ) (9,326 ) Amortization of loss 23,280 24,708 6,106 3,316 4,620 5,928 Net pension cost $18,494 $22,142 $4,252 $2,548 $1,772 $5,856 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 Non-Qualified Net Pension Cost Entergy recognized $8.5 million and $4.3 million in pension cost for its non-qualified pension plans in the second quarters of 2017 and 2016 , respectively. Reflected in the pension cost for non-qualified pension plans in the second quarter 2017 is a $4 million settlement charge recognized in June 2017 related to the payment of lump sum benefits out of this plan. Entergy recognized $13.1 million and $8.5 million in pensions costs for its non-qualified pension plans for the six months ended June 30, 2017 and 2016, respectively. Reflected in the pension cost for non-qualified pension plans for the six months ended June 30, 2017 is a $4 million settlement charge recognized in June 2017 related to the payment of lump sum benefits out of this plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the second quarters of 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $267 $47 $63 $18 $126 2016 $106 $59 $59 $16 $127 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $372 $96 $127 $36 $253 2016 $212 $118 $118 $32 $254 Reflected in Entergy Arkansas’s non-qualified pension costs in the second quarter 2017 and for the six months ended June 30, 2017 is $163 thousand in settlement charges recognized in June 2017 related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the second quarters of 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $6,729 $8,073 Interest cost on accumulated postretirement benefit obligation (APBO) 13,960 14,083 Expected return on assets (9,408 ) (10,455 ) Amortization of prior service credit (10,356 ) (11,373 ) Amortization of loss 5,476 4,554 Net other postretirement benefit cost $6,401 $4,882 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $13,458 $16,146 Interest cost on accumulated postretirement benefit obligation (APBO) 27,920 28,166 Expected return on assets (18,816 ) (20,910 ) Amortization of prior service credit (20,712 ) (22,746 ) Amortization of loss 10,952 9,108 Net other postretirement benefit cost $12,802 $9,764 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the second quarters of 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,726 $3,186 $580 $284 $744 $640 Interest cost on APBO 4,510 6,050 1,380 938 2,248 1,118 Expected return on assets (7,918 ) — (2,400 ) (2,318 ) (4,360 ) (1,434 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of loss 2,230 930 838 210 1,652 780 Net other postretirement benefit cost ($2,008 ) $6,298 ($514 ) ($1,258 ) ($874 ) $348 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 ) 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 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($89 ) $6,564 Amortization of loss (18,450 ) (2,202 ) (902 ) (21,554 ) Settlement loss — — (1,765 ) (1,765 ) ($18,515 ) $4,516 ($2,756 ) ($16,755 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 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 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, 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($130 ) $13,435 ($179 ) $13,126 Amortization of loss (36,899 ) (4,404 ) (1,822 ) (43,125 ) Settlement loss — — (1,765 ) (1,765 ) ($37,029 ) $9,031 ($3,766 ) ($31,764 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of loss (1,730 ) (930 ) (4 ) (2,664 ) ($1,730 ) $2,938 ($4 ) $1,204 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 Employer Contributions Based on current assumptions, Entergy expects to contribute $409.9 million to its qualified pension plans in 2017. As of June 30, 2017 , Entergy had contributed $176 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 2017 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2017 pension contributions $79,495 $87,923 $19,146 $9,920 $17,064 $18,180 Pension contributions made through June 2017 $34,507 $37,519 $8,251 $4,361 $7,227 $8,182 Remaining estimated pension contributions to be made in 2017 $44,988 $50,404 $10,895 $5,559 $9,837 $9,998
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 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $33,410 $35,811 Interest cost on projected benefit obligation 65,206 65,403 Expected return on assets (102,056 ) (97,366 ) Amortization of prior service cost 65 270 Amortization of loss 56,930 48,824 Net pension costs $53,555 $52,942 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $66,820 $71,622 Interest cost on projected benefit obligation 130,412 130,806 Expected return on assets (204,112 ) (194,732 ) Amortization of prior service cost 130 540 Amortization of loss 113,860 97,648 Net pension costs $107,110 $105,884 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,180 $13,850 $2,944 $1,250 $2,728 $3,072 Interest cost on projects benefit obligation 25,888 29,618 7,464 3,582 6,784 6,182 Expected return on assets (40,854 ) (46,034 ) (12,262 ) (5,600 ) (12,360 ) (9,326 ) Amortization of loss 23,280 24,708 6,106 3,316 4,620 5,928 Net pension cost $18,494 $22,142 $4,252 $2,548 $1,772 $5,856 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 Non-Qualified Net Pension Cost Entergy recognized $8.5 million and $4.3 million in pension cost for its non-qualified pension plans in the second quarters of 2017 and 2016 , respectively. Reflected in the pension cost for non-qualified pension plans in the second quarter 2017 is a $4 million settlement charge recognized in June 2017 related to the payment of lump sum benefits out of this plan. Entergy recognized $13.1 million and $8.5 million in pensions costs for its non-qualified pension plans for the six months ended June 30, 2017 and 2016, respectively. Reflected in the pension cost for non-qualified pension plans for the six months ended June 30, 2017 is a $4 million settlement charge recognized in June 2017 related to the payment of lump sum benefits out of this plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the second quarters of 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $267 $47 $63 $18 $126 2016 $106 $59 $59 $16 $127 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $372 $96 $127 $36 $253 2016 $212 $118 $118 $32 $254 Reflected in Entergy Arkansas’s non-qualified pension costs in the second quarter 2017 and for the six months ended June 30, 2017 is $163 thousand in settlement charges recognized in June 2017 related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the second quarters of 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $6,729 $8,073 Interest cost on accumulated postretirement benefit obligation (APBO) 13,960 14,083 Expected return on assets (9,408 ) (10,455 ) Amortization of prior service credit (10,356 ) (11,373 ) Amortization of loss 5,476 4,554 Net other postretirement benefit cost $6,401 $4,882 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $13,458 $16,146 Interest cost on accumulated postretirement benefit obligation (APBO) 27,920 28,166 Expected return on assets (18,816 ) (20,910 ) Amortization of prior service credit (20,712 ) (22,746 ) Amortization of loss 10,952 9,108 Net other postretirement benefit cost $12,802 $9,764 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the second quarters of 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,726 $3,186 $580 $284 $744 $640 Interest cost on APBO 4,510 6,050 1,380 938 2,248 1,118 Expected return on assets (7,918 ) — (2,400 ) (2,318 ) (4,360 ) (1,434 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of loss 2,230 930 838 210 1,652 780 Net other postretirement benefit cost ($2,008 ) $6,298 ($514 ) ($1,258 ) ($874 ) $348 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 ) 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 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($89 ) $6,564 Amortization of loss (18,450 ) (2,202 ) (902 ) (21,554 ) Settlement loss — — (1,765 ) (1,765 ) ($18,515 ) $4,516 ($2,756 ) ($16,755 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 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 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, 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($130 ) $13,435 ($179 ) $13,126 Amortization of loss (36,899 ) (4,404 ) (1,822 ) (43,125 ) Settlement loss — — (1,765 ) (1,765 ) ($37,029 ) $9,031 ($3,766 ) ($31,764 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of loss (1,730 ) (930 ) (4 ) (2,664 ) ($1,730 ) $2,938 ($4 ) $1,204 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 Employer Contributions Based on current assumptions, Entergy expects to contribute $409.9 million to its qualified pension plans in 2017. As of June 30, 2017 , Entergy had contributed $176 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 2017 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2017 pension contributions $79,495 $87,923 $19,146 $9,920 $17,064 $18,180 Pension contributions made through June 2017 $34,507 $37,519 $8,251 $4,361 $7,227 $8,182 Remaining estimated pension contributions to be made in 2017 $44,988 $50,404 $10,895 $5,559 $9,837 $9,998
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 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $33,410 $35,811 Interest cost on projected benefit obligation 65,206 65,403 Expected return on assets (102,056 ) (97,366 ) Amortization of prior service cost 65 270 Amortization of loss 56,930 48,824 Net pension costs $53,555 $52,942 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $66,820 $71,622 Interest cost on projected benefit obligation 130,412 130,806 Expected return on assets (204,112 ) (194,732 ) Amortization of prior service cost 130 540 Amortization of loss 113,860 97,648 Net pension costs $107,110 $105,884 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,180 $13,850 $2,944 $1,250 $2,728 $3,072 Interest cost on projects benefit obligation 25,888 29,618 7,464 3,582 6,784 6,182 Expected return on assets (40,854 ) (46,034 ) (12,262 ) (5,600 ) (12,360 ) (9,326 ) Amortization of loss 23,280 24,708 6,106 3,316 4,620 5,928 Net pension cost $18,494 $22,142 $4,252 $2,548 $1,772 $5,856 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 Non-Qualified Net Pension Cost Entergy recognized $8.5 million and $4.3 million in pension cost for its non-qualified pension plans in the second quarters of 2017 and 2016 , respectively. Reflected in the pension cost for non-qualified pension plans in the second quarter 2017 is a $4 million settlement charge recognized in June 2017 related to the payment of lump sum benefits out of this plan. Entergy recognized $13.1 million and $8.5 million in pensions costs for its non-qualified pension plans for the six months ended June 30, 2017 and 2016, respectively. Reflected in the pension cost for non-qualified pension plans for the six months ended June 30, 2017 is a $4 million settlement charge recognized in June 2017 related to the payment of lump sum benefits out of this plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the second quarters of 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $267 $47 $63 $18 $126 2016 $106 $59 $59 $16 $127 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $372 $96 $127 $36 $253 2016 $212 $118 $118 $32 $254 Reflected in Entergy Arkansas’s non-qualified pension costs in the second quarter 2017 and for the six months ended June 30, 2017 is $163 thousand in settlement charges recognized in June 2017 related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the second quarters of 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $6,729 $8,073 Interest cost on accumulated postretirement benefit obligation (APBO) 13,960 14,083 Expected return on assets (9,408 ) (10,455 ) Amortization of prior service credit (10,356 ) (11,373 ) Amortization of loss 5,476 4,554 Net other postretirement benefit cost $6,401 $4,882 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $13,458 $16,146 Interest cost on accumulated postretirement benefit obligation (APBO) 27,920 28,166 Expected return on assets (18,816 ) (20,910 ) Amortization of prior service credit (20,712 ) (22,746 ) Amortization of loss 10,952 9,108 Net other postretirement benefit cost $12,802 $9,764 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the second quarters of 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,726 $3,186 $580 $284 $744 $640 Interest cost on APBO 4,510 6,050 1,380 938 2,248 1,118 Expected return on assets (7,918 ) — (2,400 ) (2,318 ) (4,360 ) (1,434 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of loss 2,230 930 838 210 1,652 780 Net other postretirement benefit cost ($2,008 ) $6,298 ($514 ) ($1,258 ) ($874 ) $348 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 ) 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 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($89 ) $6,564 Amortization of loss (18,450 ) (2,202 ) (902 ) (21,554 ) Settlement loss — — (1,765 ) (1,765 ) ($18,515 ) $4,516 ($2,756 ) ($16,755 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 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 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, 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($130 ) $13,435 ($179 ) $13,126 Amortization of loss (36,899 ) (4,404 ) (1,822 ) (43,125 ) Settlement loss — — (1,765 ) (1,765 ) ($37,029 ) $9,031 ($3,766 ) ($31,764 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of loss (1,730 ) (930 ) (4 ) (2,664 ) ($1,730 ) $2,938 ($4 ) $1,204 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 Employer Contributions Based on current assumptions, Entergy expects to contribute $409.9 million to its qualified pension plans in 2017. As of June 30, 2017 , Entergy had contributed $176 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 2017 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2017 pension contributions $79,495 $87,923 $19,146 $9,920 $17,064 $18,180 Pension contributions made through June 2017 $34,507 $37,519 $8,251 $4,361 $7,227 $8,182 Remaining estimated pension contributions to be made in 2017 $44,988 $50,404 $10,895 $5,559 $9,837 $9,998

Business Segment Information

Business Segment Information	6 Months Ended
	Jun. 30, 2017
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, 2017 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the second quarters of 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $2,301,332 $317,255 $— ($37 ) $2,618,550 Income taxes $130,851 ($454,944 ) ($13,019 ) $— ($337,112 ) Consolidated net income (loss) $246,382 $223,886 ($25,001 ) ($31,899 ) $413,368 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 Entergy’s segment financial information for the six months ended June 30, 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $4,336,444 $870,622 $— ($58 ) $5,207,008 Income taxes $229,343 ($533,281 ) ($25,412 ) $— ($329,350 ) Consolidated net income (loss) $414,005 $196,689 ($47,477 ) ($63,797 ) $499,420 Total assets as of June 30, 2017 $42,263,832 $5,627,284 $1,165,157 ($3,049,236 ) $46,007,037 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 December 31, 2016 $41,098,751 $6,696,038 $1,283,816 ($3,174,171 ) $45,904,434 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions in 2016. Additional restructuring charges for the second quarter 2017 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of April 1, 2017 $94 $21 $115 Restructuring costs accrued 42 — 42 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $194 million of impairment charges in the second quarter 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Additional restructuring charges for the six months ended June 30, 2017 were comprised of the following: Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, 2017 $70 $21 $91 Restructuring costs accrued 66 — 66 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $405 million of impairment charges in the six months ended June 30, 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. 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, 2017 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the second quarters of 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $2,301,332 $317,255 $— ($37 ) $2,618,550 Income taxes $130,851 ($454,944 ) ($13,019 ) $— ($337,112 ) Consolidated net income (loss) $246,382 $223,886 ($25,001 ) ($31,899 ) $413,368 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 Entergy’s segment financial information for the six months ended June 30, 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $4,336,444 $870,622 $— ($58 ) $5,207,008 Income taxes $229,343 ($533,281 ) ($25,412 ) $— ($329,350 ) Consolidated net income (loss) $414,005 $196,689 ($47,477 ) ($63,797 ) $499,420 Total assets as of June 30, 2017 $42,263,832 $5,627,284 $1,165,157 ($3,049,236 ) $46,007,037 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 December 31, 2016 $41,098,751 $6,696,038 $1,283,816 ($3,174,171 ) $45,904,434 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions in 2016. Additional restructuring charges for the second quarter 2017 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of April 1, 2017 $94 $21 $115 Restructuring costs accrued 42 — 42 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $194 million of impairment charges in the second quarter 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Additional restructuring charges for the six months ended June 30, 2017 were comprised of the following: Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, 2017 $70 $21 $91 Restructuring costs accrued 66 — 66 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $405 million of impairment charges in the six months ended June 30, 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. 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, 2017 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the second quarters of 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $2,301,332 $317,255 $— ($37 ) $2,618,550 Income taxes $130,851 ($454,944 ) ($13,019 ) $— ($337,112 ) Consolidated net income (loss) $246,382 $223,886 ($25,001 ) ($31,899 ) $413,368 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 Entergy’s segment financial information for the six months ended June 30, 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $4,336,444 $870,622 $— ($58 ) $5,207,008 Income taxes $229,343 ($533,281 ) ($25,412 ) $— ($329,350 ) Consolidated net income (loss) $414,005 $196,689 ($47,477 ) ($63,797 ) $499,420 Total assets as of June 30, 2017 $42,263,832 $5,627,284 $1,165,157 ($3,049,236 ) $46,007,037 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 December 31, 2016 $41,098,751 $6,696,038 $1,283,816 ($3,174,171 ) $45,904,434 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions in 2016. Additional restructuring charges for the second quarter 2017 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of April 1, 2017 $94 $21 $115 Restructuring costs accrued 42 — 42 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $194 million of impairment charges in the second quarter 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Additional restructuring charges for the six months ended June 30, 2017 were comprised of the following: Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, 2017 $70 $21 $91 Restructuring costs accrued 66 — 66 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $405 million of impairment charges in the six months ended June 30, 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. 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, 2017 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the second quarters of 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $2,301,332 $317,255 $— ($37 ) $2,618,550 Income taxes $130,851 ($454,944 ) ($13,019 ) $— ($337,112 ) Consolidated net income (loss) $246,382 $223,886 ($25,001 ) ($31,899 ) $413,368 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 Entergy’s segment financial information for the six months ended June 30, 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $4,336,444 $870,622 $— ($58 ) $5,207,008 Income taxes $229,343 ($533,281 ) ($25,412 ) $— ($329,350 ) Consolidated net income (loss) $414,005 $196,689 ($47,477 ) ($63,797 ) $499,420 Total assets as of June 30, 2017 $42,263,832 $5,627,284 $1,165,157 ($3,049,236 ) $46,007,037 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 December 31, 2016 $41,098,751 $6,696,038 $1,283,816 ($3,174,171 ) $45,904,434 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions in 2016. Additional restructuring charges for the second quarter 2017 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of April 1, 2017 $94 $21 $115 Restructuring costs accrued 42 — 42 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $194 million of impairment charges in the second quarter 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Additional restructuring charges for the six months ended June 30, 2017 were comprised of the following: Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, 2017 $70 $21 $91 Restructuring costs accrued 66 — 66 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $405 million of impairment charges in the six months ended June 30, 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. 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, 2017 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the second quarters of 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $2,301,332 $317,255 $— ($37 ) $2,618,550 Income taxes $130,851 ($454,944 ) ($13,019 ) $— ($337,112 ) Consolidated net income (loss) $246,382 $223,886 ($25,001 ) ($31,899 ) $413,368 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 Entergy’s segment financial information for the six months ended June 30, 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $4,336,444 $870,622 $— ($58 ) $5,207,008 Income taxes $229,343 ($533,281 ) ($25,412 ) $— ($329,350 ) Consolidated net income (loss) $414,005 $196,689 ($47,477 ) ($63,797 ) $499,420 Total assets as of June 30, 2017 $42,263,832 $5,627,284 $1,165,157 ($3,049,236 ) $46,007,037 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 December 31, 2016 $41,098,751 $6,696,038 $1,283,816 ($3,174,171 ) $45,904,434 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions in 2016. Additional restructuring charges for the second quarter 2017 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of April 1, 2017 $94 $21 $115 Restructuring costs accrued 42 — 42 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $194 million of impairment charges in the second quarter 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Additional restructuring charges for the six months ended June 30, 2017 were comprised of the following: Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, 2017 $70 $21 $91 Restructuring costs accrued 66 — 66 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $405 million of impairment charges in the six months ended June 30, 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. 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, 2017 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the second quarters of 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $2,301,332 $317,255 $— ($37 ) $2,618,550 Income taxes $130,851 ($454,944 ) ($13,019 ) $— ($337,112 ) Consolidated net income (loss) $246,382 $223,886 ($25,001 ) ($31,899 ) $413,368 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 Entergy’s segment financial information for the six months ended June 30, 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $4,336,444 $870,622 $— ($58 ) $5,207,008 Income taxes $229,343 ($533,281 ) ($25,412 ) $— ($329,350 ) Consolidated net income (loss) $414,005 $196,689 ($47,477 ) ($63,797 ) $499,420 Total assets as of June 30, 2017 $42,263,832 $5,627,284 $1,165,157 ($3,049,236 ) $46,007,037 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 December 31, 2016 $41,098,751 $6,696,038 $1,283,816 ($3,174,171 ) $45,904,434 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions in 2016. Additional restructuring charges for the second quarter 2017 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of April 1, 2017 $94 $21 $115 Restructuring costs accrued 42 — 42 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $194 million of impairment charges in the second quarter 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Additional restructuring charges for the six months ended June 30, 2017 were comprised of the following: Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, 2017 $70 $21 $91 Restructuring costs accrued 66 — 66 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $405 million of impairment charges in the six months ended June 30, 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. 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, 2017 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the second quarters of 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $2,301,332 $317,255 $— ($37 ) $2,618,550 Income taxes $130,851 ($454,944 ) ($13,019 ) $— ($337,112 ) Consolidated net income (loss) $246,382 $223,886 ($25,001 ) ($31,899 ) $413,368 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 Entergy’s segment financial information for the six months ended June 30, 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $4,336,444 $870,622 $— ($58 ) $5,207,008 Income taxes $229,343 ($533,281 ) ($25,412 ) $— ($329,350 ) Consolidated net income (loss) $414,005 $196,689 ($47,477 ) ($63,797 ) $499,420 Total assets as of June 30, 2017 $42,263,832 $5,627,284 $1,165,157 ($3,049,236 ) $46,007,037 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 December 31, 2016 $41,098,751 $6,696,038 $1,283,816 ($3,174,171 ) $45,904,434 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions in 2016. Additional restructuring charges for the second quarter 2017 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of April 1, 2017 $94 $21 $115 Restructuring costs accrued 42 — 42 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $194 million of impairment charges in the second quarter 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Additional restructuring charges for the six months ended June 30, 2017 were comprised of the following: Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, 2017 $70 $21 $91 Restructuring costs accrued 66 — 66 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $405 million of impairment charges in the six months ended June 30, 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. 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, 2017
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, 2017 is approximately 2.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 89% for the remainder of 2017 , of which approximately 59% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2017 is 15 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of June 30, 2017 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $3 million in cash collateral and $19 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2016 , derivative contracts with three counterparties were in a liability position (approximately $8 million total). In addition to the corporate guarantee, $2 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. If the Entergy Corporation credit rating falls below investment grade, 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, 2017 is 34,696,750 MMBtu for Entergy, including 29,110,800 MMBtu for Entergy Louisiana and 5,585,950 MMBtu for Entergy Mississippi. Credit support for these natural gas swaps is covered by master agreements that do not require collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2017, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2017 through May 31, 2018. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2017 is 106,060 GWh for Entergy, including 24,188 GWh for Entergy Arkansas, 47,173 GWh for Entergy Louisiana, 14,075 GWh for Entergy Mississippi, 5,316 GWh for Entergy New Orleans, and 14,572 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of June 30, 2017 and December 31, 2016. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas and Entergy Mississippi as of June 30, 2017 and December 31, 2016. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of June 30, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location 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) $40 ($23) $17 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($9) $10 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $15 ($15) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $12 ($10) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $16 ($3) $13 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $61 ($4) $57 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $5 $— $5 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $25 ($14) $11 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($6) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $11 ($10) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $16 ($7) $9 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $18 ($13) $5 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $13 $— $13 Utility Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $18 ($17) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $4 ($4) $— Entergy Wholesale Commodities (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $3 million held as of June 30, 2017 and $2 million posted as of December 31, 2016. Also excludes $19 million in letters of credit held as of June 30, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $13 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 (a) Before taxes of $4 million and $16 million for the three months ended June 30, 2017 and 2016, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain Income Statement location Amount of gain (In Millions) (In Millions) 2017 Electricity swaps and options $93 Competitive businesses operating revenues $64 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 (a) Before taxes of $22 million and $70 million for the six months ended June 30, 2017 and 2016, 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, 2017 and 2016 was $5 million and ($3) million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2017 and 2016 was $4 million and ($0.3) million , respectively. Based on market prices as of June 30, 2017 , unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $39 million of net unrealized gains. Approximately $30 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 income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of loss recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) FTRs $— Purchased power expense (b) $44 Electricity swaps and options ($5) (c) Competitive business operating revenues $— 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 ($10) (c) Competitive business operating revenues ($6) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) Financial transmission rights $— Purchased power expense (b) $75 Electricity swaps and options $4 (c) Competitive business operating revenues $— 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) Financial transmission rights $— Purchased power expense (b) $59 Electricity swaps and options $15 (c) Competitive business operating revenues ($9) (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 2017 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $8.3 Entergy Arkansas Financial transmission rights Prepayments and other $28.3 Entergy Louisiana Financial transmission rights Prepayments and other $9.1 Entergy Mississippi Financial transmission rights Prepayments and other $5.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.5 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $4.5 Entergy Louisiana Natural gas swaps Other current liabilities $0.8 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $10.9 Entergy Louisiana Natural gas swaps Prepayments and other $2.3 Entergy Mississippi Natural gas swaps Prepayments and other $0.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.5 Entergy Louisiana Financial transmission rights Prepayments and other $3.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 Entergy New Orleans Financial transmission rights Prepayments and other $3.1 Entergy Texas (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. As of December 31, 2016, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.4) (a) Entergy Mississippi FTRs Purchased power expense $10.5 (b) Entergy Arkansas FTRs Purchased power expense $14.3 (b) Entergy Louisiana FTRs Purchased power expense $8.5 (b) Entergy Mississippi FTRs Purchased power expense $3.4 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 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 The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $15.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $29.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $11.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $12.1 (b) Entergy Texas 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 Financial transmission rights Purchased power expense $13.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $32.1 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $6.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options 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
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, 2017 is approximately 2.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 89% for the remainder of 2017 , of which approximately 59% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2017 is 15 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of June 30, 2017 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $3 million in cash collateral and $19 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2016 , derivative contracts with three counterparties were in a liability position (approximately $8 million total). In addition to the corporate guarantee, $2 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. If the Entergy Corporation credit rating falls below investment grade, 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, 2017 is 34,696,750 MMBtu for Entergy, including 29,110,800 MMBtu for Entergy Louisiana and 5,585,950 MMBtu for Entergy Mississippi. Credit support for these natural gas swaps is covered by master agreements that do not require collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2017, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2017 through May 31, 2018. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2017 is 106,060 GWh for Entergy, including 24,188 GWh for Entergy Arkansas, 47,173 GWh for Entergy Louisiana, 14,075 GWh for Entergy Mississippi, 5,316 GWh for Entergy New Orleans, and 14,572 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of June 30, 2017 and December 31, 2016. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas and Entergy Mississippi as of June 30, 2017 and December 31, 2016. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of June 30, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location 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) $40 ($23) $17 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($9) $10 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $15 ($15) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $12 ($10) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $16 ($3) $13 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $61 ($4) $57 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $5 $— $5 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $25 ($14) $11 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($6) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $11 ($10) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $16 ($7) $9 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $18 ($13) $5 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $13 $— $13 Utility Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $18 ($17) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $4 ($4) $— Entergy Wholesale Commodities (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $3 million held as of June 30, 2017 and $2 million posted as of December 31, 2016. Also excludes $19 million in letters of credit held as of June 30, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $13 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 (a) Before taxes of $4 million and $16 million for the three months ended June 30, 2017 and 2016, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain Income Statement location Amount of gain (In Millions) (In Millions) 2017 Electricity swaps and options $93 Competitive businesses operating revenues $64 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 (a) Before taxes of $22 million and $70 million for the six months ended June 30, 2017 and 2016, 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, 2017 and 2016 was $5 million and ($3) million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2017 and 2016 was $4 million and ($0.3) million , respectively. Based on market prices as of June 30, 2017 , unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $39 million of net unrealized gains. Approximately $30 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 income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of loss recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) FTRs $— Purchased power expense (b) $44 Electricity swaps and options ($5) (c) Competitive business operating revenues $— 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 ($10) (c) Competitive business operating revenues ($6) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) Financial transmission rights $— Purchased power expense (b) $75 Electricity swaps and options $4 (c) Competitive business operating revenues $— 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) Financial transmission rights $— Purchased power expense (b) $59 Electricity swaps and options $15 (c) Competitive business operating revenues ($9) (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 2017 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $8.3 Entergy Arkansas Financial transmission rights Prepayments and other $28.3 Entergy Louisiana Financial transmission rights Prepayments and other $9.1 Entergy Mississippi Financial transmission rights Prepayments and other $5.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.5 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $4.5 Entergy Louisiana Natural gas swaps Other current liabilities $0.8 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $10.9 Entergy Louisiana Natural gas swaps Prepayments and other $2.3 Entergy Mississippi Natural gas swaps Prepayments and other $0.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.5 Entergy Louisiana Financial transmission rights Prepayments and other $3.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 Entergy New Orleans Financial transmission rights Prepayments and other $3.1 Entergy Texas (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. As of December 31, 2016, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.4) (a) Entergy Mississippi FTRs Purchased power expense $10.5 (b) Entergy Arkansas FTRs Purchased power expense $14.3 (b) Entergy Louisiana FTRs Purchased power expense $8.5 (b) Entergy Mississippi FTRs Purchased power expense $3.4 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 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 The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $15.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $29.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $11.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $12.1 (b) Entergy Texas 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 Financial transmission rights Purchased power expense $13.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $32.1 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $6.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options 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
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, 2017 is approximately 2.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 89% for the remainder of 2017 , of which approximately 59% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2017 is 15 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of June 30, 2017 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $3 million in cash collateral and $19 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2016 , derivative contracts with three counterparties were in a liability position (approximately $8 million total). In addition to the corporate guarantee, $2 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. If the Entergy Corporation credit rating falls below investment grade, 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, 2017 is 34,696,750 MMBtu for Entergy, including 29,110,800 MMBtu for Entergy Louisiana and 5,585,950 MMBtu for Entergy Mississippi. Credit support for these natural gas swaps is covered by master agreements that do not require collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2017, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2017 through May 31, 2018. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2017 is 106,060 GWh for Entergy, including 24,188 GWh for Entergy Arkansas, 47,173 GWh for Entergy Louisiana, 14,075 GWh for Entergy Mississippi, 5,316 GWh for Entergy New Orleans, and 14,572 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of June 30, 2017 and December 31, 2016. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas and Entergy Mississippi as of June 30, 2017 and December 31, 2016. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of June 30, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location 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) $40 ($23) $17 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($9) $10 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $15 ($15) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $12 ($10) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $16 ($3) $13 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $61 ($4) $57 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $5 $— $5 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $25 ($14) $11 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($6) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $11 ($10) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $16 ($7) $9 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $18 ($13) $5 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $13 $— $13 Utility Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $18 ($17) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $4 ($4) $— Entergy Wholesale Commodities (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $3 million held as of June 30, 2017 and $2 million posted as of December 31, 2016. Also excludes $19 million in letters of credit held as of June 30, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $13 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 (a) Before taxes of $4 million and $16 million for the three months ended June 30, 2017 and 2016, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain Income Statement location Amount of gain (In Millions) (In Millions) 2017 Electricity swaps and options $93 Competitive businesses operating revenues $64 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 (a) Before taxes of $22 million and $70 million for the six months ended June 30, 2017 and 2016, 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, 2017 and 2016 was $5 million and ($3) million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2017 and 2016 was $4 million and ($0.3) million , respectively. Based on market prices as of June 30, 2017 , unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $39 million of net unrealized gains. Approximately $30 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 income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of loss recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) FTRs $— Purchased power expense (b) $44 Electricity swaps and options ($5) (c) Competitive business operating revenues $— 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 ($10) (c) Competitive business operating revenues ($6) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) Financial transmission rights $— Purchased power expense (b) $75 Electricity swaps and options $4 (c) Competitive business operating revenues $— 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) Financial transmission rights $— Purchased power expense (b) $59 Electricity swaps and options $15 (c) Competitive business operating revenues ($9) (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 2017 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $8.3 Entergy Arkansas Financial transmission rights Prepayments and other $28.3 Entergy Louisiana Financial transmission rights Prepayments and other $9.1 Entergy Mississippi Financial transmission rights Prepayments and other $5.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.5 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $4.5 Entergy Louisiana Natural gas swaps Other current liabilities $0.8 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $10.9 Entergy Louisiana Natural gas swaps Prepayments and other $2.3 Entergy Mississippi Natural gas swaps Prepayments and other $0.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.5 Entergy Louisiana Financial transmission rights Prepayments and other $3.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 Entergy New Orleans Financial transmission rights Prepayments and other $3.1 Entergy Texas (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. As of December 31, 2016, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.4) (a) Entergy Mississippi FTRs Purchased power expense $10.5 (b) Entergy Arkansas FTRs Purchased power expense $14.3 (b) Entergy Louisiana FTRs Purchased power expense $8.5 (b) Entergy Mississippi FTRs Purchased power expense $3.4 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 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 The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $15.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $29.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $11.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $12.1 (b) Entergy Texas 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 Financial transmission rights Purchased power expense $13.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $32.1 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $6.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options 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
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, 2017 is approximately 2.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 89% for the remainder of 2017 , of which approximately 59% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2017 is 15 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of June 30, 2017 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $3 million in cash collateral and $19 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2016 , derivative contracts with three counterparties were in a liability position (approximately $8 million total). In addition to the corporate guarantee, $2 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. If the Entergy Corporation credit rating falls below investment grade, 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, 2017 is 34,696,750 MMBtu for Entergy, including 29,110,800 MMBtu for Entergy Louisiana and 5,585,950 MMBtu for Entergy Mississippi. Credit support for these natural gas swaps is covered by master agreements that do not require collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2017, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2017 through May 31, 2018. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2017 is 106,060 GWh for Entergy, including 24,188 GWh for Entergy Arkansas, 47,173 GWh for Entergy Louisiana, 14,075 GWh for Entergy Mississippi, 5,316 GWh for Entergy New Orleans, and 14,572 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of June 30, 2017 and December 31, 2016. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas and Entergy Mississippi as of June 30, 2017 and December 31, 2016. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of June 30, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location 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) $40 ($23) $17 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($9) $10 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $15 ($15) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $12 ($10) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $16 ($3) $13 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $61 ($4) $57 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $5 $— $5 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $25 ($14) $11 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($6) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $11 ($10) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $16 ($7) $9 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $18 ($13) $5 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $13 $— $13 Utility Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $18 ($17) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $4 ($4) $— Entergy Wholesale Commodities (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $3 million held as of June 30, 2017 and $2 million posted as of December 31, 2016. Also excludes $19 million in letters of credit held as of June 30, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $13 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 (a) Before taxes of $4 million and $16 million for the three months ended June 30, 2017 and 2016, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain Income Statement location Amount of gain (In Millions) (In Millions) 2017 Electricity swaps and options $93 Competitive businesses operating revenues $64 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 (a) Before taxes of $22 million and $70 million for the six months ended June 30, 2017 and 2016, 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, 2017 and 2016 was $5 million and ($3) million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2017 and 2016 was $4 million and ($0.3) million , respectively. Based on market prices as of June 30, 2017 , unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $39 million of net unrealized gains. Approximately $30 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 income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of loss recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) FTRs $— Purchased power expense (b) $44 Electricity swaps and options ($5) (c) Competitive business operating revenues $— 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 ($10) (c) Competitive business operating revenues ($6) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) Financial transmission rights $— Purchased power expense (b) $75 Electricity swaps and options $4 (c) Competitive business operating revenues $— 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) Financial transmission rights $— Purchased power expense (b) $59 Electricity swaps and options $15 (c) Competitive business operating revenues ($9) (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 2017 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $8.3 Entergy Arkansas Financial transmission rights Prepayments and other $28.3 Entergy Louisiana Financial transmission rights Prepayments and other $9.1 Entergy Mississippi Financial transmission rights Prepayments and other $5.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.5 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $4.5 Entergy Louisiana Natural gas swaps Other current liabilities $0.8 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $10.9 Entergy Louisiana Natural gas swaps Prepayments and other $2.3 Entergy Mississippi Natural gas swaps Prepayments and other $0.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.5 Entergy Louisiana Financial transmission rights Prepayments and other $3.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 Entergy New Orleans Financial transmission rights Prepayments and other $3.1 Entergy Texas (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. As of December 31, 2016, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.4) (a) Entergy Mississippi FTRs Purchased power expense $10.5 (b) Entergy Arkansas FTRs Purchased power expense $14.3 (b) Entergy Louisiana FTRs Purchased power expense $8.5 (b) Entergy Mississippi FTRs Purchased power expense $3.4 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 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 The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $15.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $29.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $11.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $12.1 (b) Entergy Texas 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 Financial transmission rights Purchased power expense $13.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $32.1 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $6.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options 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
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, 2017 is approximately 2.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 89% for the remainder of 2017 , of which approximately 59% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2017 is 15 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of June 30, 2017 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $3 million in cash collateral and $19 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2016 , derivative contracts with three counterparties were in a liability position (approximately $8 million total). In addition to the corporate guarantee, $2 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. If the Entergy Corporation credit rating falls below investment grade, 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, 2017 is 34,696,750 MMBtu for Entergy, including 29,110,800 MMBtu for Entergy Louisiana and 5,585,950 MMBtu for Entergy Mississippi. Credit support for these natural gas swaps is covered by master agreements that do not require collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2017, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2017 through May 31, 2018. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2017 is 106,060 GWh for Entergy, including 24,188 GWh for Entergy Arkansas, 47,173 GWh for Entergy Louisiana, 14,075 GWh for Entergy Mississippi, 5,316 GWh for Entergy New Orleans, and 14,572 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of June 30, 2017 and December 31, 2016. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas and Entergy Mississippi as of June 30, 2017 and December 31, 2016. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of June 30, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location 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) $40 ($23) $17 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($9) $10 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $15 ($15) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $12 ($10) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $16 ($3) $13 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $61 ($4) $57 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $5 $— $5 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $25 ($14) $11 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($6) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $11 ($10) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $16 ($7) $9 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $18 ($13) $5 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $13 $— $13 Utility Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $18 ($17) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $4 ($4) $— Entergy Wholesale Commodities (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $3 million held as of June 30, 2017 and $2 million posted as of December 31, 2016. Also excludes $19 million in letters of credit held as of June 30, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $13 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 (a) Before taxes of $4 million and $16 million for the three months ended June 30, 2017 and 2016, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain Income Statement location Amount of gain (In Millions) (In Millions) 2017 Electricity swaps and options $93 Competitive businesses operating revenues $64 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 (a) Before taxes of $22 million and $70 million for the six months ended June 30, 2017 and 2016, 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, 2017 and 2016 was $5 million and ($3) million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2017 and 2016 was $4 million and ($0.3) million , respectively. Based on market prices as of June 30, 2017 , unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $39 million of net unrealized gains. Approximately $30 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 income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of loss recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) FTRs $— Purchased power expense (b) $44 Electricity swaps and options ($5) (c) Competitive business operating revenues $— 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 ($10) (c) Competitive business operating revenues ($6) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) Financial transmission rights $— Purchased power expense (b) $75 Electricity swaps and options $4 (c) Competitive business operating revenues $— 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) Financial transmission rights $— Purchased power expense (b) $59 Electricity swaps and options $15 (c) Competitive business operating revenues ($9) (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 2017 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $8.3 Entergy Arkansas Financial transmission rights Prepayments and other $28.3 Entergy Louisiana Financial transmission rights Prepayments and other $9.1 Entergy Mississippi Financial transmission rights Prepayments and other $5.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.5 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $4.5 Entergy Louisiana Natural gas swaps Other current liabilities $0.8 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $10.9 Entergy Louisiana Natural gas swaps Prepayments and other $2.3 Entergy Mississippi Natural gas swaps Prepayments and other $0.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.5 Entergy Louisiana Financial transmission rights Prepayments and other $3.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 Entergy New Orleans Financial transmission rights Prepayments and other $3.1 Entergy Texas (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. As of December 31, 2016, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.4) (a) Entergy Mississippi FTRs Purchased power expense $10.5 (b) Entergy Arkansas FTRs Purchased power expense $14.3 (b) Entergy Louisiana FTRs Purchased power expense $8.5 (b) Entergy Mississippi FTRs Purchased power expense $3.4 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 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 The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $15.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $29.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $11.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $12.1 (b) Entergy Texas 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 Financial transmission rights Purchased power expense $13.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $32.1 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $6.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options 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
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, 2017 is approximately 2.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 89% for the remainder of 2017 , of which approximately 59% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2017 is 15 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of June 30, 2017 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $3 million in cash collateral and $19 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2016 , derivative contracts with three counterparties were in a liability position (approximately $8 million total). In addition to the corporate guarantee, $2 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. If the Entergy Corporation credit rating falls below investment grade, 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, 2017 is 34,696,750 MMBtu for Entergy, including 29,110,800 MMBtu for Entergy Louisiana and 5,585,950 MMBtu for Entergy Mississippi. Credit support for these natural gas swaps is covered by master agreements that do not require collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2017, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2017 through May 31, 2018. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2017 is 106,060 GWh for Entergy, including 24,188 GWh for Entergy Arkansas, 47,173 GWh for Entergy Louisiana, 14,075 GWh for Entergy Mississippi, 5,316 GWh for Entergy New Orleans, and 14,572 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of June 30, 2017 and December 31, 2016. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas and Entergy Mississippi as of June 30, 2017 and December 31, 2016. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of June 30, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location 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) $40 ($23) $17 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($9) $10 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $15 ($15) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $12 ($10) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $16 ($3) $13 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $61 ($4) $57 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $5 $— $5 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $25 ($14) $11 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($6) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $11 ($10) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $16 ($7) $9 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $18 ($13) $5 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $13 $— $13 Utility Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $18 ($17) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $4 ($4) $— Entergy Wholesale Commodities (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $3 million held as of June 30, 2017 and $2 million posted as of December 31, 2016. Also excludes $19 million in letters of credit held as of June 30, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $13 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 (a) Before taxes of $4 million and $16 million for the three months ended June 30, 2017 and 2016, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain Income Statement location Amount of gain (In Millions) (In Millions) 2017 Electricity swaps and options $93 Competitive businesses operating revenues $64 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 (a) Before taxes of $22 million and $70 million for the six months ended June 30, 2017 and 2016, 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, 2017 and 2016 was $5 million and ($3) million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2017 and 2016 was $4 million and ($0.3) million , respectively. Based on market prices as of June 30, 2017 , unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $39 million of net unrealized gains. Approximately $30 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 income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of loss recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) FTRs $— Purchased power expense (b) $44 Electricity swaps and options ($5) (c) Competitive business operating revenues $— 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 ($10) (c) Competitive business operating revenues ($6) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) Financial transmission rights $— Purchased power expense (b) $75 Electricity swaps and options $4 (c) Competitive business operating revenues $— 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) Financial transmission rights $— Purchased power expense (b) $59 Electricity swaps and options $15 (c) Competitive business operating revenues ($9) (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 2017 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $8.3 Entergy Arkansas Financial transmission rights Prepayments and other $28.3 Entergy Louisiana Financial transmission rights Prepayments and other $9.1 Entergy Mississippi Financial transmission rights Prepayments and other $5.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.5 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $4.5 Entergy Louisiana Natural gas swaps Other current liabilities $0.8 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $10.9 Entergy Louisiana Natural gas swaps Prepayments and other $2.3 Entergy Mississippi Natural gas swaps Prepayments and other $0.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.5 Entergy Louisiana Financial transmission rights Prepayments and other $3.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 Entergy New Orleans Financial transmission rights Prepayments and other $3.1 Entergy Texas (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. As of December 31, 2016, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.4) (a) Entergy Mississippi FTRs Purchased power expense $10.5 (b) Entergy Arkansas FTRs Purchased power expense $14.3 (b) Entergy Louisiana FTRs Purchased power expense $8.5 (b) Entergy Mississippi FTRs Purchased power expense $3.4 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 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 The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $15.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $29.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $11.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $12.1 (b) Entergy Texas 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 Financial transmission rights Purchased power expense $13.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $32.1 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $6.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options 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
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, 2017 is approximately 2.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 89% for the remainder of 2017 , of which approximately 59% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2017 is 15 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of June 30, 2017 , there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $3 million in cash collateral and $19 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2016 , derivative contracts with three counterparties were in a liability position (approximately $8 million total). In addition to the corporate guarantee, $2 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. If the Entergy Corporation credit rating falls below investment grade, 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, 2017 is 34,696,750 MMBtu for Entergy, including 29,110,800 MMBtu for Entergy Louisiana and 5,585,950 MMBtu for Entergy Mississippi. Credit support for these natural gas swaps is covered by master agreements that do not require collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2017, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2017 through May 31, 2018. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2017 is 106,060 GWh for Entergy, including 24,188 GWh for Entergy Arkansas, 47,173 GWh for Entergy Louisiana, 14,075 GWh for Entergy Mississippi, 5,316 GWh for Entergy New Orleans, and 14,572 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of June 30, 2017 and December 31, 2016. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas and Entergy Mississippi as of June 30, 2017 and December 31, 2016. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of June 30, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location 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) $40 ($23) $17 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($9) $10 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $15 ($15) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $12 ($10) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $16 ($3) $13 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $61 ($4) $57 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $5 $— $5 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $25 ($14) $11 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($6) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $11 ($10) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $16 ($7) $9 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $18 ($13) $5 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $13 $— $13 Utility Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $18 ($17) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $4 ($4) $— Entergy Wholesale Commodities (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $3 million held as of June 30, 2017 and $2 million posted as of December 31, 2016. Also excludes $19 million in letters of credit held as of June 30, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $13 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 (a) Before taxes of $4 million and $16 million for the three months ended June 30, 2017 and 2016, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain Income Statement location Amount of gain (In Millions) (In Millions) 2017 Electricity swaps and options $93 Competitive businesses operating revenues $64 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 (a) Before taxes of $22 million and $70 million for the six months ended June 30, 2017 and 2016, 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, 2017 and 2016 was $5 million and ($3) million , respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the six months ended June 30, 2017 and 2016 was $4 million and ($0.3) million , respectively. Based on market prices as of June 30, 2017 , unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $39 million of net unrealized gains. Approximately $30 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 income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of loss recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) FTRs $— Purchased power expense (b) $44 Electricity swaps and options ($5) (c) Competitive business operating revenues $— 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 ($10) (c) Competitive business operating revenues ($6) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) Financial transmission rights $— Purchased power expense (b) $75 Electricity swaps and options $4 (c) Competitive business operating revenues $— 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) Financial transmission rights $— Purchased power expense (b) $59 Electricity swaps and options $15 (c) Competitive business operating revenues ($9) (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 2017 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $8.3 Entergy Arkansas Financial transmission rights Prepayments and other $28.3 Entergy Louisiana Financial transmission rights Prepayments and other $9.1 Entergy Mississippi Financial transmission rights Prepayments and other $5.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.5 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $4.5 Entergy Louisiana Natural gas swaps Other current liabilities $0.8 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $10.9 Entergy Louisiana Natural gas swaps Prepayments and other $2.3 Entergy Mississippi Natural gas swaps Prepayments and other $0.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.5 Entergy Louisiana Financial transmission rights Prepayments and other $3.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 Entergy New Orleans Financial transmission rights Prepayments and other $3.1 Entergy Texas (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. As of December 31, 2016, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.4) (a) Entergy Mississippi FTRs Purchased power expense $10.5 (b) Entergy Arkansas FTRs Purchased power expense $14.3 (b) Entergy Louisiana FTRs Purchased power expense $8.5 (b) Entergy Mississippi FTRs Purchased power expense $3.4 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 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 The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $15.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $29.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $11.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $12.1 (b) Entergy Texas 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 Financial transmission rights Purchased power expense $13.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $32.1 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $6.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group. The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options 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

Decommissioning Trust Funds

Decommissioning Trust Funds	6 Months Ended
	Jun. 30, 2017
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, Indian Point 2, Indian Point 3, Vermont Yankee, and Palisades. The funds are invested primarily in equity securities, fixed-rate debt securities, and cash and cash equivalents. See Note 16 to the financial statements in the Form 10-K for discussion of the trust transfer agreement with NYPA to transfer the decommissioning trust funds and decommissioning liabilities for the Indian Point 3 and FitzPatrick plants to Entergy. In January 2017, NYPA transferred to Entergy the Indian Point 3 decommissioning trust fund with a fair value of $726 million and the FitzPatrick decommissioning trust fund with a fair value of $793 million . As discussed in Note 13 to the financial statements herein, in March 2017, Entergy closed on the sale of the FitzPatrick plant to Exelon. As part of the transaction, Entergy transferred the FitzPatrick decommissioning trust fund to Exelon. The FitzPatrick decommissioning trust fund had a disposition-date fair value of $805 million and was classified as held for sale within other deferred debits as of December 31, 2016. 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, Indian Point 2, Indian Point 3, 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $4,389 $1,857 $1 Debt Securities 2,408 45 15 Total $6,797 $1,902 $16 Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,511 $1,673 $1 Debt Securities 2,213 34 27 Total $5,724 $1,707 $28 The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of June 30, 2017 are $465 million for Indian Point 1, $591 million for Indian Point 2, $758 million for Indian Point 3, $434 million for Palisades, $1,010 million for Pilgrim, and $595 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. 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 $441 million and $399 million as of June 30, 2017 and December 31, 2016 , respectively. The amortized cost of debt securities was $2,378 million as of June 30, 2017 and $2,212 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 3.21% , an average duration of approximately 6.14 years, and an average maturity of approximately 9.96 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $2 $1 $997 $12 More than 12 months — — 47 3 Total $2 $1 $1,044 $15 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $23 $1 $1,169 $26 More than 12 months 1 — 20 1 Total $24 $1 $1,189 $27 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $106 $125 1 year - 5 years 805 763 5 years - 10 years 795 719 10 years - 15 years 111 109 15 years - 20 years 88 73 20 years+ 503 424 Total $2,408 $2,213 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $949 million and $504 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $61 million and $10 million , respectively, and gross losses of $2 million and $2 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the six months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $1,463 million and $1,233 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $70 million and $20 million , respectively, and gross losses of $7 million and $5 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $556.3 $308.0 $— Debt Securities 328.0 3.3 2.3 Total $884.3 $311.3 $2.3 2016 Equity Securities $525.4 $281.5 $— Debt Securities 309.3 3.4 4.2 Total $834.7 $284.9 $4.2 The amortized cost of debt securities was $327 million as of June 30, 2017 and $310.1 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 2.53% , an average duration of approximately 5.83 years, and an average maturity of approximately 6.87 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $118.1 $1.7 More than 12 months — — 10.1 0.6 Total $— $— $128.2 $2.3 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $146.7 $4.2 More than 12 months — — — — Total $— $— $146.7 $4.2 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $16.8 $16.7 1 year - 5 years 102.6 106.2 5 years - 10 years 183.5 161.2 10 years - 15 years 4.4 7.7 15 years - 20 years 1.1 1.0 20 years+ 19.6 16.5 Total $328.0 $309.3 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $131.3 million and $45.2 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $11.2 million and $0.4 million , respectively, and gross losses of $0.1 million and $0.2 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $167.3 million and $103.8 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $11.7 million and $1.2 million , respectively, and gross losses of $0.2 million and $0.3 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $756.6 $395.6 $— Debt Securities 464.1 10.9 2.9 Total $1,220.7 $406.5 $2.9 2016 Equity Securities $715.9 $346.6 $— Debt Securities 424.8 8.0 5.0 Total $1,140.7 $354.6 $5.0 The amortized cost of debt securities was $456.1 million as of June 30, 2017 and $421.9 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 3.79% , an average duration of approximately 5.8 years, and an average maturity of approximately 11.49 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $164.4 $2.4 More than 12 months — — 9.7 0.5 Total $— $— $174.1 $2.9 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $198.8 $4.8 More than 12 months — — 4.8 0.2 Total $— $— $203.6 $5.0 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $28.5 $31.4 1 year - 5 years 105.2 99.1 5 years - 10 years 131.9 122.8 10 years - 15 years 44.3 41.4 15 years - 20 years 38.6 30.9 20 years+ 115.6 99.2 Total $464.1 $424.8 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $85 million and $69.7 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $5 million and $1.7 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, 2017 and 2016 , proceeds from the dispositions of securities amounted to $125.6 million and $123.5 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $5 million and $2.6 million , respectively, and gross losses of $0.3 million and $0.1 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $516.9 $257.6 $— Debt Securities 322.5 3.3 2.3 Total $839.4 $260.9 $2.3 2016 Equity Securities $473.9 $221.9 $0.1 Debt Securities 306.6 2.0 4.5 Total $780.5 $223.9 $4.6 The amortized cost of debt securities was $321.5 million as of June 30, 2017 and $309.1 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 2.37% , an average duration of approximately 6.45 years, and an average maturity of approximately 8.84 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $199.5 $2.0 More than 12 months — — 8.6 0.3 Total $— $— $208.1 $2.3 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $220.9 $4.4 More than 12 months — 0.1 0.8 0.1 Total $— $0.1 $221.7 $4.5 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $8.6 $6.6 1 year - 5 years 159.6 188.2 5 years - 10 years 86.4 78.5 10 years - 15 years 2.3 1.3 15 years - 20 years 7.8 7.8 20 years+ 57.8 24.2 Total $322.5 $306.6 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $177.7 million and $100.9 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $0.4 million and $0.9 million , respectively, and gross losses of $0.6 million and $0.1 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $253.5 million and $289.4 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $0.5 million and $2.5 million , respectively, and gross losses of $1.3 million and $0.4 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates investment securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred. The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three and six months ended June 30, 2017 and 2016 . The assessment of whether an investment in an equity security has suffered an other-than-temporary impairment is 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 record material charges to other income for the three and six months ended June 30, 2017 and 2016 , resulting from the recognition of the other-than-temporary impairment of certain equity securities held in its decommissioning trust funds.
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, Indian Point 2, Indian Point 3, Vermont Yankee, and Palisades. The funds are invested primarily in equity securities, fixed-rate debt securities, and cash and cash equivalents. See Note 16 to the financial statements in the Form 10-K for discussion of the trust transfer agreement with NYPA to transfer the decommissioning trust funds and decommissioning liabilities for the Indian Point 3 and FitzPatrick plants to Entergy. In January 2017, NYPA transferred to Entergy the Indian Point 3 decommissioning trust fund with a fair value of $726 million and the FitzPatrick decommissioning trust fund with a fair value of $793 million . As discussed in Note 13 to the financial statements herein, in March 2017, Entergy closed on the sale of the FitzPatrick plant to Exelon. As part of the transaction, Entergy transferred the FitzPatrick decommissioning trust fund to Exelon. The FitzPatrick decommissioning trust fund had a disposition-date fair value of $805 million and was classified as held for sale within other deferred debits as of December 31, 2016. 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, Indian Point 2, Indian Point 3, 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $4,389 $1,857 $1 Debt Securities 2,408 45 15 Total $6,797 $1,902 $16 Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,511 $1,673 $1 Debt Securities 2,213 34 27 Total $5,724 $1,707 $28 The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of June 30, 2017 are $465 million for Indian Point 1, $591 million for Indian Point 2, $758 million for Indian Point 3, $434 million for Palisades, $1,010 million for Pilgrim, and $595 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. 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 $441 million and $399 million as of June 30, 2017 and December 31, 2016 , respectively. The amortized cost of debt securities was $2,378 million as of June 30, 2017 and $2,212 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 3.21% , an average duration of approximately 6.14 years, and an average maturity of approximately 9.96 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $2 $1 $997 $12 More than 12 months — — 47 3 Total $2 $1 $1,044 $15 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $23 $1 $1,169 $26 More than 12 months 1 — 20 1 Total $24 $1 $1,189 $27 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $106 $125 1 year - 5 years 805 763 5 years - 10 years 795 719 10 years - 15 years 111 109 15 years - 20 years 88 73 20 years+ 503 424 Total $2,408 $2,213 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $949 million and $504 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $61 million and $10 million , respectively, and gross losses of $2 million and $2 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the six months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $1,463 million and $1,233 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $70 million and $20 million , respectively, and gross losses of $7 million and $5 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $556.3 $308.0 $— Debt Securities 328.0 3.3 2.3 Total $884.3 $311.3 $2.3 2016 Equity Securities $525.4 $281.5 $— Debt Securities 309.3 3.4 4.2 Total $834.7 $284.9 $4.2 The amortized cost of debt securities was $327 million as of June 30, 2017 and $310.1 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 2.53% , an average duration of approximately 5.83 years, and an average maturity of approximately 6.87 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $118.1 $1.7 More than 12 months — — 10.1 0.6 Total $— $— $128.2 $2.3 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $146.7 $4.2 More than 12 months — — — — Total $— $— $146.7 $4.2 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $16.8 $16.7 1 year - 5 years 102.6 106.2 5 years - 10 years 183.5 161.2 10 years - 15 years 4.4 7.7 15 years - 20 years 1.1 1.0 20 years+ 19.6 16.5 Total $328.0 $309.3 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $131.3 million and $45.2 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $11.2 million and $0.4 million , respectively, and gross losses of $0.1 million and $0.2 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $167.3 million and $103.8 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $11.7 million and $1.2 million , respectively, and gross losses of $0.2 million and $0.3 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $756.6 $395.6 $— Debt Securities 464.1 10.9 2.9 Total $1,220.7 $406.5 $2.9 2016 Equity Securities $715.9 $346.6 $— Debt Securities 424.8 8.0 5.0 Total $1,140.7 $354.6 $5.0 The amortized cost of debt securities was $456.1 million as of June 30, 2017 and $421.9 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 3.79% , an average duration of approximately 5.8 years, and an average maturity of approximately 11.49 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $164.4 $2.4 More than 12 months — — 9.7 0.5 Total $— $— $174.1 $2.9 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $198.8 $4.8 More than 12 months — — 4.8 0.2 Total $— $— $203.6 $5.0 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $28.5 $31.4 1 year - 5 years 105.2 99.1 5 years - 10 years 131.9 122.8 10 years - 15 years 44.3 41.4 15 years - 20 years 38.6 30.9 20 years+ 115.6 99.2 Total $464.1 $424.8 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $85 million and $69.7 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $5 million and $1.7 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, 2017 and 2016 , proceeds from the dispositions of securities amounted to $125.6 million and $123.5 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $5 million and $2.6 million , respectively, and gross losses of $0.3 million and $0.1 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $516.9 $257.6 $— Debt Securities 322.5 3.3 2.3 Total $839.4 $260.9 $2.3 2016 Equity Securities $473.9 $221.9 $0.1 Debt Securities 306.6 2.0 4.5 Total $780.5 $223.9 $4.6 The amortized cost of debt securities was $321.5 million as of June 30, 2017 and $309.1 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 2.37% , an average duration of approximately 6.45 years, and an average maturity of approximately 8.84 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $199.5 $2.0 More than 12 months — — 8.6 0.3 Total $— $— $208.1 $2.3 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $220.9 $4.4 More than 12 months — 0.1 0.8 0.1 Total $— $0.1 $221.7 $4.5 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $8.6 $6.6 1 year - 5 years 159.6 188.2 5 years - 10 years 86.4 78.5 10 years - 15 years 2.3 1.3 15 years - 20 years 7.8 7.8 20 years+ 57.8 24.2 Total $322.5 $306.6 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $177.7 million and $100.9 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $0.4 million and $0.9 million , respectively, and gross losses of $0.6 million and $0.1 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $253.5 million and $289.4 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $0.5 million and $2.5 million , respectively, and gross losses of $1.3 million and $0.4 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates investment securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred. The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three and six months ended June 30, 2017 and 2016 . The assessment of whether an investment in an equity security has suffered an other-than-temporary impairment is 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 record material charges to other income for the three and six months ended June 30, 2017 and 2016 , resulting from the recognition of the other-than-temporary impairment of certain equity securities held in its decommissioning trust funds.
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, Indian Point 2, Indian Point 3, Vermont Yankee, and Palisades. The funds are invested primarily in equity securities, fixed-rate debt securities, and cash and cash equivalents. See Note 16 to the financial statements in the Form 10-K for discussion of the trust transfer agreement with NYPA to transfer the decommissioning trust funds and decommissioning liabilities for the Indian Point 3 and FitzPatrick plants to Entergy. In January 2017, NYPA transferred to Entergy the Indian Point 3 decommissioning trust fund with a fair value of $726 million and the FitzPatrick decommissioning trust fund with a fair value of $793 million . As discussed in Note 13 to the financial statements herein, in March 2017, Entergy closed on the sale of the FitzPatrick plant to Exelon. As part of the transaction, Entergy transferred the FitzPatrick decommissioning trust fund to Exelon. The FitzPatrick decommissioning trust fund had a disposition-date fair value of $805 million and was classified as held for sale within other deferred debits as of December 31, 2016. 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, Indian Point 2, Indian Point 3, 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $4,389 $1,857 $1 Debt Securities 2,408 45 15 Total $6,797 $1,902 $16 Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,511 $1,673 $1 Debt Securities 2,213 34 27 Total $5,724 $1,707 $28 The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of June 30, 2017 are $465 million for Indian Point 1, $591 million for Indian Point 2, $758 million for Indian Point 3, $434 million for Palisades, $1,010 million for Pilgrim, and $595 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. 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 $441 million and $399 million as of June 30, 2017 and December 31, 2016 , respectively. The amortized cost of debt securities was $2,378 million as of June 30, 2017 and $2,212 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 3.21% , an average duration of approximately 6.14 years, and an average maturity of approximately 9.96 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $2 $1 $997 $12 More than 12 months — — 47 3 Total $2 $1 $1,044 $15 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $23 $1 $1,169 $26 More than 12 months 1 — 20 1 Total $24 $1 $1,189 $27 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $106 $125 1 year - 5 years 805 763 5 years - 10 years 795 719 10 years - 15 years 111 109 15 years - 20 years 88 73 20 years+ 503 424 Total $2,408 $2,213 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $949 million and $504 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $61 million and $10 million , respectively, and gross losses of $2 million and $2 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the six months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $1,463 million and $1,233 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $70 million and $20 million , respectively, and gross losses of $7 million and $5 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $556.3 $308.0 $— Debt Securities 328.0 3.3 2.3 Total $884.3 $311.3 $2.3 2016 Equity Securities $525.4 $281.5 $— Debt Securities 309.3 3.4 4.2 Total $834.7 $284.9 $4.2 The amortized cost of debt securities was $327 million as of June 30, 2017 and $310.1 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 2.53% , an average duration of approximately 5.83 years, and an average maturity of approximately 6.87 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $118.1 $1.7 More than 12 months — — 10.1 0.6 Total $— $— $128.2 $2.3 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $146.7 $4.2 More than 12 months — — — — Total $— $— $146.7 $4.2 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $16.8 $16.7 1 year - 5 years 102.6 106.2 5 years - 10 years 183.5 161.2 10 years - 15 years 4.4 7.7 15 years - 20 years 1.1 1.0 20 years+ 19.6 16.5 Total $328.0 $309.3 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $131.3 million and $45.2 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $11.2 million and $0.4 million , respectively, and gross losses of $0.1 million and $0.2 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $167.3 million and $103.8 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $11.7 million and $1.2 million , respectively, and gross losses of $0.2 million and $0.3 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $756.6 $395.6 $— Debt Securities 464.1 10.9 2.9 Total $1,220.7 $406.5 $2.9 2016 Equity Securities $715.9 $346.6 $— Debt Securities 424.8 8.0 5.0 Total $1,140.7 $354.6 $5.0 The amortized cost of debt securities was $456.1 million as of June 30, 2017 and $421.9 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 3.79% , an average duration of approximately 5.8 years, and an average maturity of approximately 11.49 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $164.4 $2.4 More than 12 months — — 9.7 0.5 Total $— $— $174.1 $2.9 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $198.8 $4.8 More than 12 months — — 4.8 0.2 Total $— $— $203.6 $5.0 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $28.5 $31.4 1 year - 5 years 105.2 99.1 5 years - 10 years 131.9 122.8 10 years - 15 years 44.3 41.4 15 years - 20 years 38.6 30.9 20 years+ 115.6 99.2 Total $464.1 $424.8 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $85 million and $69.7 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $5 million and $1.7 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, 2017 and 2016 , proceeds from the dispositions of securities amounted to $125.6 million and $123.5 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $5 million and $2.6 million , respectively, and gross losses of $0.3 million and $0.1 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $516.9 $257.6 $— Debt Securities 322.5 3.3 2.3 Total $839.4 $260.9 $2.3 2016 Equity Securities $473.9 $221.9 $0.1 Debt Securities 306.6 2.0 4.5 Total $780.5 $223.9 $4.6 The amortized cost of debt securities was $321.5 million as of June 30, 2017 and $309.1 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 2.37% , an average duration of approximately 6.45 years, and an average maturity of approximately 8.84 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $199.5 $2.0 More than 12 months — — 8.6 0.3 Total $— $— $208.1 $2.3 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $220.9 $4.4 More than 12 months — 0.1 0.8 0.1 Total $— $0.1 $221.7 $4.5 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $8.6 $6.6 1 year - 5 years 159.6 188.2 5 years - 10 years 86.4 78.5 10 years - 15 years 2.3 1.3 15 years - 20 years 7.8 7.8 20 years+ 57.8 24.2 Total $322.5 $306.6 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $177.7 million and $100.9 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $0.4 million and $0.9 million , respectively, and gross losses of $0.6 million and $0.1 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $253.5 million and $289.4 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $0.5 million and $2.5 million , respectively, and gross losses of $1.3 million and $0.4 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates investment securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred. The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three and six months ended June 30, 2017 and 2016 . The assessment of whether an investment in an equity security has suffered an other-than-temporary impairment is 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 record material charges to other income for the three and six months ended June 30, 2017 and 2016 , resulting from the recognition of the other-than-temporary impairment of certain equity securities held in its decommissioning trust funds.
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, Indian Point 2, Indian Point 3, Vermont Yankee, and Palisades. The funds are invested primarily in equity securities, fixed-rate debt securities, and cash and cash equivalents. See Note 16 to the financial statements in the Form 10-K for discussion of the trust transfer agreement with NYPA to transfer the decommissioning trust funds and decommissioning liabilities for the Indian Point 3 and FitzPatrick plants to Entergy. In January 2017, NYPA transferred to Entergy the Indian Point 3 decommissioning trust fund with a fair value of $726 million and the FitzPatrick decommissioning trust fund with a fair value of $793 million . As discussed in Note 13 to the financial statements herein, in March 2017, Entergy closed on the sale of the FitzPatrick plant to Exelon. As part of the transaction, Entergy transferred the FitzPatrick decommissioning trust fund to Exelon. The FitzPatrick decommissioning trust fund had a disposition-date fair value of $805 million and was classified as held for sale within other deferred debits as of December 31, 2016. 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, Indian Point 2, Indian Point 3, 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $4,389 $1,857 $1 Debt Securities 2,408 45 15 Total $6,797 $1,902 $16 Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,511 $1,673 $1 Debt Securities 2,213 34 27 Total $5,724 $1,707 $28 The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of June 30, 2017 are $465 million for Indian Point 1, $591 million for Indian Point 2, $758 million for Indian Point 3, $434 million for Palisades, $1,010 million for Pilgrim, and $595 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. 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 $441 million and $399 million as of June 30, 2017 and December 31, 2016 , respectively. The amortized cost of debt securities was $2,378 million as of June 30, 2017 and $2,212 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 3.21% , an average duration of approximately 6.14 years, and an average maturity of approximately 9.96 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $2 $1 $997 $12 More than 12 months — — 47 3 Total $2 $1 $1,044 $15 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $23 $1 $1,169 $26 More than 12 months 1 — 20 1 Total $24 $1 $1,189 $27 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $106 $125 1 year - 5 years 805 763 5 years - 10 years 795 719 10 years - 15 years 111 109 15 years - 20 years 88 73 20 years+ 503 424 Total $2,408 $2,213 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $949 million and $504 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $61 million and $10 million , respectively, and gross losses of $2 million and $2 million , respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the six months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $1,463 million and $1,233 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $70 million and $20 million , respectively, and gross losses of $7 million and $5 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $556.3 $308.0 $— Debt Securities 328.0 3.3 2.3 Total $884.3 $311.3 $2.3 2016 Equity Securities $525.4 $281.5 $— Debt Securities 309.3 3.4 4.2 Total $834.7 $284.9 $4.2 The amortized cost of debt securities was $327 million as of June 30, 2017 and $310.1 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 2.53% , an average duration of approximately 5.83 years, and an average maturity of approximately 6.87 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $118.1 $1.7 More than 12 months — — 10.1 0.6 Total $— $— $128.2 $2.3 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $146.7 $4.2 More than 12 months — — — — Total $— $— $146.7 $4.2 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $16.8 $16.7 1 year - 5 years 102.6 106.2 5 years - 10 years 183.5 161.2 10 years - 15 years 4.4 7.7 15 years - 20 years 1.1 1.0 20 years+ 19.6 16.5 Total $328.0 $309.3 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $131.3 million and $45.2 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $11.2 million and $0.4 million , respectively, and gross losses of $0.1 million and $0.2 million , respectively were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $167.3 million and $103.8 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $11.7 million and $1.2 million , respectively, and gross losses of $0.2 million and $0.3 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $756.6 $395.6 $— Debt Securities 464.1 10.9 2.9 Total $1,220.7 $406.5 $2.9 2016 Equity Securities $715.9 $346.6 $— Debt Securities 424.8 8.0 5.0 Total $1,140.7 $354.6 $5.0 The amortized cost of debt securities was $456.1 million as of June 30, 2017 and $421.9 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 3.79% , an average duration of approximately 5.8 years, and an average maturity of approximately 11.49 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $164.4 $2.4 More than 12 months — — 9.7 0.5 Total $— $— $174.1 $2.9 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $198.8 $4.8 More than 12 months — — 4.8 0.2 Total $— $— $203.6 $5.0 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $28.5 $31.4 1 year - 5 years 105.2 99.1 5 years - 10 years 131.9 122.8 10 years - 15 years 44.3 41.4 15 years - 20 years 38.6 30.9 20 years+ 115.6 99.2 Total $464.1 $424.8 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $85 million and $69.7 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $5 million and $1.7 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, 2017 and 2016 , proceeds from the dispositions of securities amounted to $125.6 million and $123.5 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $5 million and $2.6 million , respectively, and gross losses of $0.3 million and $0.1 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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $516.9 $257.6 $— Debt Securities 322.5 3.3 2.3 Total $839.4 $260.9 $2.3 2016 Equity Securities $473.9 $221.9 $0.1 Debt Securities 306.6 2.0 4.5 Total $780.5 $223.9 $4.6 The amortized cost of debt securities was $321.5 million as of June 30, 2017 and $309.1 million as of December 31, 2016 . As of June 30, 2017 , the debt securities have an average coupon rate of approximately 2.37% , an average duration of approximately 6.45 years, and an average maturity of approximately 8.84 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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $199.5 $2.0 More than 12 months — — 8.6 0.3 Total $— $— $208.1 $2.3 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $220.9 $4.4 More than 12 months — 0.1 0.8 0.1 Total $— $0.1 $221.7 $4.5 The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $8.6 $6.6 1 year - 5 years 159.6 188.2 5 years - 10 years 86.4 78.5 10 years - 15 years 2.3 1.3 15 years - 20 years 7.8 7.8 20 years+ 57.8 24.2 Total $322.5 $306.6 During the three months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $177.7 million and $100.9 million , respectively. During the three months ended June 30, 2017 and 2016 , gross gains of $0.4 million and $0.9 million , respectively, and gross losses of $0.6 million and $0.1 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2017 and 2016 , proceeds from the dispositions of securities amounted to $253.5 million and $289.4 million , respectively. During the six months ended June 30, 2017 and 2016 , gross gains of $0.5 million and $2.5 million , respectively, and gross losses of $1.3 million and $0.4 million , respectively, were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates investment securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred. The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three and six months ended June 30, 2017 and 2016 . The assessment of whether an investment in an equity security has suffered an other-than-temporary impairment is 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 record material charges to other income for the three and six months ended June 30, 2017 and 2016 , resulting from the recognition of the other-than-temporary impairment of certain equity securities held in its decommissioning trust funds.

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2017
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits and other income tax matters involving Entergy. The following are updates to that discussion. As discussed in the Form 10-K, in the second quarter 2016, Entergy made a tax election to treat as a corporation for federal income tax purposes its subsidiary that owned the FitzPatrick nuclear power plant. The effect of the election was that the plant and associated assets were deemed to be contributed to a new corporation for federal income tax purposes, which created permanent and temporary differences, as discussed in the Form 10-K. One permanent difference, which increased tax expense in 2016 under the applicable accounting standards, was the reduction to the plant’s tax basis to the extent that it exceeded its fair market value. Entergy sold the FitzPatrick plant on March 31, 2017. The removal of the contingencies regarding the sale of the plant and the receipt of NRC approval for the sale allowed Entergy to re-determine the plant’s tax basis, using the closing price as indicative of a higher fair market value for the plant. The re-determined basis resulted in a $44 million income tax benefit in the first quarter 2017. In the second quarter 2017, Entergy made tax elections to treat as corporations for federal income tax purposes two subsidiaries that each own an Entergy Wholesale Commodities nuclear power plant. This resulted in a constructive contribution of all the assets and liabilities associated with the plants to new subsidiary corporations for federal income tax purposes, and generated both permanent and temporary differences under the income tax accounting standards. The constructive contributions required the Entergy subsidiary that constructively contributed the assets and liabilities to recognize the plants’ nuclear decommissioning liabilities for income tax purposes resulting in permanent differences. The accrual of the nuclear decommissioning liabilities required Entergy to recognize a gain for income tax purposes, a portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiaries. Recognition of the gain and the increase in tax basis of the assets represents a temporary difference. The permanent differences reduced income tax expense, net of unrecognized tax benefits, by $373 million . In the first quarter 2017, Entergy implemented ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” Entergy will now prospectively recognize all income tax effects related to share-based payments through the income statement. In the first quarter 2017, stock option expirations, along with other stock compensation activity, resulted in the write-off of $11.5 million of deferred tax assets. Entergy’s stock-based compensation plans are discussed in Note 12 to the financial statements in the Form 10-K.
Entergy Arkansas [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits and other income tax matters involving Entergy. The following are updates to that discussion. As discussed in the Form 10-K, in the second quarter 2016, Entergy made a tax election to treat as a corporation for federal income tax purposes its subsidiary that owned the FitzPatrick nuclear power plant. The effect of the election was that the plant and associated assets were deemed to be contributed to a new corporation for federal income tax purposes, which created permanent and temporary differences, as discussed in the Form 10-K. One permanent difference, which increased tax expense in 2016 under the applicable accounting standards, was the reduction to the plant’s tax basis to the extent that it exceeded its fair market value. Entergy sold the FitzPatrick plant on March 31, 2017. The removal of the contingencies regarding the sale of the plant and the receipt of NRC approval for the sale allowed Entergy to re-determine the plant’s tax basis, using the closing price as indicative of a higher fair market value for the plant. The re-determined basis resulted in a $44 million income tax benefit in the first quarter 2017. In the second quarter 2017, Entergy made tax elections to treat as corporations for federal income tax purposes two subsidiaries that each own an Entergy Wholesale Commodities nuclear power plant. This resulted in a constructive contribution of all the assets and liabilities associated with the plants to new subsidiary corporations for federal income tax purposes, and generated both permanent and temporary differences under the income tax accounting standards. The constructive contributions required the Entergy subsidiary that constructively contributed the assets and liabilities to recognize the plants’ nuclear decommissioning liabilities for income tax purposes resulting in permanent differences. The accrual of the nuclear decommissioning liabilities required Entergy to recognize a gain for income tax purposes, a portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiaries. Recognition of the gain and the increase in tax basis of the assets represents a temporary difference. The permanent differences reduced income tax expense, net of unrecognized tax benefits, by $373 million . In the first quarter 2017, Entergy implemented ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” Entergy will now prospectively recognize all income tax effects related to share-based payments through the income statement. In the first quarter 2017, stock option expirations, along with other stock compensation activity, resulted in the write-off of $11.5 million of deferred tax assets. Entergy’s stock-based compensation plans are discussed in Note 12 to the financial statements in the Form 10-K.
Entergy Louisiana [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits and other income tax matters involving Entergy. The following are updates to that discussion. As discussed in the Form 10-K, in the second quarter 2016, Entergy made a tax election to treat as a corporation for federal income tax purposes its subsidiary that owned the FitzPatrick nuclear power plant. The effect of the election was that the plant and associated assets were deemed to be contributed to a new corporation for federal income tax purposes, which created permanent and temporary differences, as discussed in the Form 10-K. One permanent difference, which increased tax expense in 2016 under the applicable accounting standards, was the reduction to the plant’s tax basis to the extent that it exceeded its fair market value. Entergy sold the FitzPatrick plant on March 31, 2017. The removal of the contingencies regarding the sale of the plant and the receipt of NRC approval for the sale allowed Entergy to re-determine the plant’s tax basis, using the closing price as indicative of a higher fair market value for the plant. The re-determined basis resulted in a $44 million income tax benefit in the first quarter 2017. In the second quarter 2017, Entergy made tax elections to treat as corporations for federal income tax purposes two subsidiaries that each own an Entergy Wholesale Commodities nuclear power plant. This resulted in a constructive contribution of all the assets and liabilities associated with the plants to new subsidiary corporations for federal income tax purposes, and generated both permanent and temporary differences under the income tax accounting standards. The constructive contributions required the Entergy subsidiary that constructively contributed the assets and liabilities to recognize the plants’ nuclear decommissioning liabilities for income tax purposes resulting in permanent differences. The accrual of the nuclear decommissioning liabilities required Entergy to recognize a gain for income tax purposes, a portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiaries. Recognition of the gain and the increase in tax basis of the assets represents a temporary difference. The permanent differences reduced income tax expense, net of unrecognized tax benefits, by $373 million . In the first quarter 2017, Entergy implemented ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” Entergy will now prospectively recognize all income tax effects related to share-based payments through the income statement. In the first quarter 2017, stock option expirations, along with other stock compensation activity, resulted in the write-off of $11.5 million of deferred tax assets. Entergy’s stock-based compensation plans are discussed in Note 12 to the financial statements in the Form 10-K.
Entergy Mississippi [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits and other income tax matters involving Entergy. The following are updates to that discussion. As discussed in the Form 10-K, in the second quarter 2016, Entergy made a tax election to treat as a corporation for federal income tax purposes its subsidiary that owned the FitzPatrick nuclear power plant. The effect of the election was that the plant and associated assets were deemed to be contributed to a new corporation for federal income tax purposes, which created permanent and temporary differences, as discussed in the Form 10-K. One permanent difference, which increased tax expense in 2016 under the applicable accounting standards, was the reduction to the plant’s tax basis to the extent that it exceeded its fair market value. Entergy sold the FitzPatrick plant on March 31, 2017. The removal of the contingencies regarding the sale of the plant and the receipt of NRC approval for the sale allowed Entergy to re-determine the plant’s tax basis, using the closing price as indicative of a higher fair market value for the plant. The re-determined basis resulted in a $44 million income tax benefit in the first quarter 2017. In the second quarter 2017, Entergy made tax elections to treat as corporations for federal income tax purposes two subsidiaries that each own an Entergy Wholesale Commodities nuclear power plant. This resulted in a constructive contribution of all the assets and liabilities associated with the plants to new subsidiary corporations for federal income tax purposes, and generated both permanent and temporary differences under the income tax accounting standards. The constructive contributions required the Entergy subsidiary that constructively contributed the assets and liabilities to recognize the plants’ nuclear decommissioning liabilities for income tax purposes resulting in permanent differences. The accrual of the nuclear decommissioning liabilities required Entergy to recognize a gain for income tax purposes, a portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiaries. Recognition of the gain and the increase in tax basis of the assets represents a temporary difference. The permanent differences reduced income tax expense, net of unrecognized tax benefits, by $373 million . In the first quarter 2017, Entergy implemented ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” Entergy will now prospectively recognize all income tax effects related to share-based payments through the income statement. In the first quarter 2017, stock option expirations, along with other stock compensation activity, resulted in the write-off of $11.5 million of deferred tax assets. Entergy’s stock-based compensation plans are discussed in Note 12 to the financial statements in the Form 10-K.
Entergy New Orleans [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits and other income tax matters involving Entergy. The following are updates to that discussion. As discussed in the Form 10-K, in the second quarter 2016, Entergy made a tax election to treat as a corporation for federal income tax purposes its subsidiary that owned the FitzPatrick nuclear power plant. The effect of the election was that the plant and associated assets were deemed to be contributed to a new corporation for federal income tax purposes, which created permanent and temporary differences, as discussed in the Form 10-K. One permanent difference, which increased tax expense in 2016 under the applicable accounting standards, was the reduction to the plant’s tax basis to the extent that it exceeded its fair market value. Entergy sold the FitzPatrick plant on March 31, 2017. The removal of the contingencies regarding the sale of the plant and the receipt of NRC approval for the sale allowed Entergy to re-determine the plant’s tax basis, using the closing price as indicative of a higher fair market value for the plant. The re-determined basis resulted in a $44 million income tax benefit in the first quarter 2017. In the second quarter 2017, Entergy made tax elections to treat as corporations for federal income tax purposes two subsidiaries that each own an Entergy Wholesale Commodities nuclear power plant. This resulted in a constructive contribution of all the assets and liabilities associated with the plants to new subsidiary corporations for federal income tax purposes, and generated both permanent and temporary differences under the income tax accounting standards. The constructive contributions required the Entergy subsidiary that constructively contributed the assets and liabilities to recognize the plants’ nuclear decommissioning liabilities for income tax purposes resulting in permanent differences. The accrual of the nuclear decommissioning liabilities required Entergy to recognize a gain for income tax purposes, a portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiaries. Recognition of the gain and the increase in tax basis of the assets represents a temporary difference. The permanent differences reduced income tax expense, net of unrecognized tax benefits, by $373 million . In the first quarter 2017, Entergy implemented ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” Entergy will now prospectively recognize all income tax effects related to share-based payments through the income statement. In the first quarter 2017, stock option expirations, along with other stock compensation activity, resulted in the write-off of $11.5 million of deferred tax assets. Entergy’s stock-based compensation plans are discussed in Note 12 to the financial statements in the Form 10-K.
Entergy Texas [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits and other income tax matters involving Entergy. The following are updates to that discussion. As discussed in the Form 10-K, in the second quarter 2016, Entergy made a tax election to treat as a corporation for federal income tax purposes its subsidiary that owned the FitzPatrick nuclear power plant. The effect of the election was that the plant and associated assets were deemed to be contributed to a new corporation for federal income tax purposes, which created permanent and temporary differences, as discussed in the Form 10-K. One permanent difference, which increased tax expense in 2016 under the applicable accounting standards, was the reduction to the plant’s tax basis to the extent that it exceeded its fair market value. Entergy sold the FitzPatrick plant on March 31, 2017. The removal of the contingencies regarding the sale of the plant and the receipt of NRC approval for the sale allowed Entergy to re-determine the plant’s tax basis, using the closing price as indicative of a higher fair market value for the plant. The re-determined basis resulted in a $44 million income tax benefit in the first quarter 2017. In the second quarter 2017, Entergy made tax elections to treat as corporations for federal income tax purposes two subsidiaries that each own an Entergy Wholesale Commodities nuclear power plant. This resulted in a constructive contribution of all the assets and liabilities associated with the plants to new subsidiary corporations for federal income tax purposes, and generated both permanent and temporary differences under the income tax accounting standards. The constructive contributions required the Entergy subsidiary that constructively contributed the assets and liabilities to recognize the plants’ nuclear decommissioning liabilities for income tax purposes resulting in permanent differences. The accrual of the nuclear decommissioning liabilities required Entergy to recognize a gain for income tax purposes, a portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiaries. Recognition of the gain and the increase in tax basis of the assets represents a temporary difference. The permanent differences reduced income tax expense, net of unrecognized tax benefits, by $373 million . In the first quarter 2017, Entergy implemented ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” Entergy will now prospectively recognize all income tax effects related to share-based payments through the income statement. In the first quarter 2017, stock option expirations, along with other stock compensation activity, resulted in the write-off of $11.5 million of deferred tax assets. Entergy’s stock-based compensation plans are discussed in Note 12 to the financial statements in the Form 10-K.
System Energy [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits and other income tax matters involving Entergy. The following are updates to that discussion. As discussed in the Form 10-K, in the second quarter 2016, Entergy made a tax election to treat as a corporation for federal income tax purposes its subsidiary that owned the FitzPatrick nuclear power plant. The effect of the election was that the plant and associated assets were deemed to be contributed to a new corporation for federal income tax purposes, which created permanent and temporary differences, as discussed in the Form 10-K. One permanent difference, which increased tax expense in 2016 under the applicable accounting standards, was the reduction to the plant’s tax basis to the extent that it exceeded its fair market value. Entergy sold the FitzPatrick plant on March 31, 2017. The removal of the contingencies regarding the sale of the plant and the receipt of NRC approval for the sale allowed Entergy to re-determine the plant’s tax basis, using the closing price as indicative of a higher fair market value for the plant. The re-determined basis resulted in a $44 million income tax benefit in the first quarter 2017. In the second quarter 2017, Entergy made tax elections to treat as corporations for federal income tax purposes two subsidiaries that each own an Entergy Wholesale Commodities nuclear power plant. This resulted in a constructive contribution of all the assets and liabilities associated with the plants to new subsidiary corporations for federal income tax purposes, and generated both permanent and temporary differences under the income tax accounting standards. The constructive contributions required the Entergy subsidiary that constructively contributed the assets and liabilities to recognize the plants’ nuclear decommissioning liabilities for income tax purposes resulting in permanent differences. The accrual of the nuclear decommissioning liabilities required Entergy to recognize a gain for income tax purposes, a portion of which resulted in an increase in tax basis of the assets constructively contributed to the subsidiaries. Recognition of the gain and the increase in tax basis of the assets represents a temporary difference. The permanent differences reduced income tax expense, net of unrecognized tax benefits, by $373 million . In the first quarter 2017, Entergy implemented ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” Entergy will now prospectively recognize all income tax effects related to share-based payments through the income statement. In the first quarter 2017, stock option expirations, along with other stock compensation activity, resulted in the write-off of $11.5 million of deferred tax assets. Entergy’s stock-based compensation plans are discussed in Note 12 to the financial statements in the Form 10-K.

Property, Plant, And Equipment

Property, Plant, And Equipment	6 Months Ended
	Jun. 30, 2017
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, 2017 are $198 million for Entergy, $47.8 million for Entergy Arkansas, $55.1 million for Entergy Louisiana, $5.3 million for Entergy Mississippi, $1.1 million for Entergy New Orleans, $15.2 million for Entergy Texas, and $28.1 million for System Energy. Construction expenditures included in accounts payable at December 31, 2016 are $253 million for Entergy, $40.9 million for Entergy Arkansas, $114.8 million for Entergy Louisiana, $11.5 million for Entergy Mississippi, $2.3 million for Entergy New Orleans, $9.3 million for Entergy Texas, and $6.2 million for System Energy.
Entergy Arkansas [Member]
Property, Plant And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at June 30, 2017 are $198 million for Entergy, $47.8 million for Entergy Arkansas, $55.1 million for Entergy Louisiana, $5.3 million for Entergy Mississippi, $1.1 million for Entergy New Orleans, $15.2 million for Entergy Texas, and $28.1 million for System Energy. Construction expenditures included in accounts payable at December 31, 2016 are $253 million for Entergy, $40.9 million for Entergy Arkansas, $114.8 million for Entergy Louisiana, $11.5 million for Entergy Mississippi, $2.3 million for Entergy New Orleans, $9.3 million for Entergy Texas, and $6.2 million for System Energy.
Entergy Louisiana [Member]
Property, Plant And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at June 30, 2017 are $198 million for Entergy, $47.8 million for Entergy Arkansas, $55.1 million for Entergy Louisiana, $5.3 million for Entergy Mississippi, $1.1 million for Entergy New Orleans, $15.2 million for Entergy Texas, and $28.1 million for System Energy. Construction expenditures included in accounts payable at December 31, 2016 are $253 million for Entergy, $40.9 million for Entergy Arkansas, $114.8 million for Entergy Louisiana, $11.5 million for Entergy Mississippi, $2.3 million for Entergy New Orleans, $9.3 million for Entergy Texas, and $6.2 million for System Energy.
Entergy Mississippi [Member]
Property, Plant And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at June 30, 2017 are $198 million for Entergy, $47.8 million for Entergy Arkansas, $55.1 million for Entergy Louisiana, $5.3 million for Entergy Mississippi, $1.1 million for Entergy New Orleans, $15.2 million for Entergy Texas, and $28.1 million for System Energy. Construction expenditures included in accounts payable at December 31, 2016 are $253 million for Entergy, $40.9 million for Entergy Arkansas, $114.8 million for Entergy Louisiana, $11.5 million for Entergy Mississippi, $2.3 million for Entergy New Orleans, $9.3 million for Entergy Texas, and $6.2 million for System Energy.
Entergy New Orleans [Member]
Property, Plant And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at June 30, 2017 are $198 million for Entergy, $47.8 million for Entergy Arkansas, $55.1 million for Entergy Louisiana, $5.3 million for Entergy Mississippi, $1.1 million for Entergy New Orleans, $15.2 million for Entergy Texas, and $28.1 million for System Energy. Construction expenditures included in accounts payable at December 31, 2016 are $253 million for Entergy, $40.9 million for Entergy Arkansas, $114.8 million for Entergy Louisiana, $11.5 million for Entergy Mississippi, $2.3 million for Entergy New Orleans, $9.3 million for Entergy Texas, and $6.2 million for System Energy.
Entergy Texas [Member]
Property, Plant And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at June 30, 2017 are $198 million for Entergy, $47.8 million for Entergy Arkansas, $55.1 million for Entergy Louisiana, $5.3 million for Entergy Mississippi, $1.1 million for Entergy New Orleans, $15.2 million for Entergy Texas, and $28.1 million for System Energy. Construction expenditures included in accounts payable at December 31, 2016 are $253 million for Entergy, $40.9 million for Entergy Arkansas, $114.8 million for Entergy Louisiana, $11.5 million for Entergy Mississippi, $2.3 million for Entergy New Orleans, $9.3 million for Entergy Texas, and $6.2 million for System Energy.
System Energy [Member]
Property, Plant And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at June 30, 2017 are $198 million for Entergy, $47.8 million for Entergy Arkansas, $55.1 million for Entergy Louisiana, $5.3 million for Entergy Mississippi, $1.1 million for Entergy New Orleans, $15.2 million for Entergy Texas, and $28.1 million for System Energy. Construction expenditures included in accounts payable at December 31, 2016 are $253 million for Entergy, $40.9 million for Entergy Arkansas, $114.8 million for Entergy Louisiana, $11.5 million for Entergy Mississippi, $2.3 million for Entergy New Orleans, $9.3 million for Entergy Texas, and $6.2 million for System Energy.

Variable Interest Entities

Variable Interest Entities	6 Months Ended
	Jun. 30, 2017
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. 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 through March 2016. See Note 10 to the financial statements in the Form 10-K for a discussion of Entergy Louisiana’s purchase of the Waterford 3 leased assets. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments on its lease, including interest, of $8.6 million in the six months ended June 30, 2017 and $8.6 million in the six months ended June 30, 2016 .
Entergy Arkansas [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. 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 through March 2016. See Note 10 to the financial statements in the Form 10-K for a discussion of Entergy Louisiana’s purchase of the Waterford 3 leased assets. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments on its lease, including interest, of $8.6 million in the six months ended June 30, 2017 and $8.6 million in the six months ended June 30, 2016 .
Entergy Louisiana [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. 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 through March 2016. See Note 10 to the financial statements in the Form 10-K for a discussion of Entergy Louisiana’s purchase of the Waterford 3 leased assets. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments on its lease, including interest, of $8.6 million in the six months ended June 30, 2017 and $8.6 million in the six months ended June 30, 2016 .
Entergy Mississippi [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. 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 through March 2016. See Note 10 to the financial statements in the Form 10-K for a discussion of Entergy Louisiana’s purchase of the Waterford 3 leased assets. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments on its lease, including interest, of $8.6 million in the six months ended June 30, 2017 and $8.6 million in the six months ended June 30, 2016 .
Entergy New Orleans [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. 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 through March 2016. See Note 10 to the financial statements in the Form 10-K for a discussion of Entergy Louisiana’s purchase of the Waterford 3 leased assets. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments on its lease, including interest, of $8.6 million in the six months ended June 30, 2017 and $8.6 million in the six months ended June 30, 2016 .
Entergy Texas [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. 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 through March 2016. See Note 10 to the financial statements in the Form 10-K for a discussion of Entergy Louisiana’s purchase of the Waterford 3 leased assets. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments on its lease, including interest, of $8.6 million in the six months ended June 30, 2017 and $8.6 million in the six months ended June 30, 2016 .
System Energy [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. 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 through March 2016. See Note 10 to the financial statements in the Form 10-K for a discussion of Entergy Louisiana’s purchase of the Waterford 3 leased assets. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments on its lease, including interest, of $8.6 million in the six months ended June 30, 2017 and $8.6 million in the six months ended June 30, 2016 .

Dispositions Dispositions

Dispositions Dispositions	6 Months Ended
	Jun. 30, 2017
Business Acquisition [Line Items]
Acquisitions and Dispositions [Text Block]	DISPOSITIONS (Entergy Corporation) In March 2017 the NRC approved the sale of the FitzPatrick plant, an 838 MW nuclear power plant owned by Entergy in the Entergy Wholesale Commodities segment, to Exelon. The transaction closed in March 2017 for a purchase price of $110 million , including the $10 million non-refundable signing fee paid in August 2016, in addition to the assumption by Exelon of certain liabilities related to the FitzPatrick plant, resulting in a pre-tax gain on the sale of $16 million . At the transaction close, Exelon paid an additional $8 million for the proration of certain expenses prepaid by Entergy. As discussed in Note 10 to the financial statements herein, as a result of the sale of FitzPatrick on March 31, 2017, Entergy re-determined the plant’s tax basis, resulting in a $44 million income tax benefit in the first quarter 2017. The assets and liabilities associated with the sale of FitzPatrick to Exelon were classified as held for sale on Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet as of December 31, 2016. The disposition-date fair value of the decommissioning trust fund was $805 million , classified within other deferred debits, and the disposition-date fair value of the asset retirement obligation was $727 million , classified within other non-current liabilities. The transaction also included property, plant, and equipment with a net book value of zero , materials and supplies, and prepaid assets. As discussed in Note 14 to the financial statements in the Form 10-K, Entergy entered into a reimbursement agreement with Exelon pursuant to which Exelon reimbursed Entergy for specified out-of-pocket costs associated with Entergy’s operation of FitzPatrick. In the first quarter 2017, Entergy billed Exelon for reimbursement of $98 million of other operation and maintenance expenses, $7 million in lost operating revenues, and $3 million in taxes other than income taxes, partially offset by a $10 million defueling credit to Exelon.

Asset Retirement Obligations As

Asset Retirement Obligations Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2017
Asset Retirement Obligation Disclosure [Text Block]	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. Following is an update to that discussion. In the second quarter 2017, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $35.9 million reduction in its decommissioning cost liability, along with a corresponding reduction in the related asset retirement cost asset that will be depreciated over the remaining life of the unit.
Entergy Arkansas [Member]
Asset Retirement Obligation Disclosure [Text Block]	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. Following is an update to that discussion. In the second quarter 2017, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $35.9 million reduction in its decommissioning cost liability, along with a corresponding reduction in the related asset retirement cost asset that will be depreciated over the remaining life of the unit.
Entergy Louisiana [Member]
Asset Retirement Obligation Disclosure [Text Block]	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. Following is an update to that discussion. In the second quarter 2017, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $35.9 million reduction in its decommissioning cost liability, along with a corresponding reduction in the related asset retirement cost asset that will be depreciated over the remaining life of the unit.
Entergy Mississippi [Member]
Asset Retirement Obligation Disclosure [Text Block]	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. Following is an update to that discussion. In the second quarter 2017, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $35.9 million reduction in its decommissioning cost liability, along with a corresponding reduction in the related asset retirement cost asset that will be depreciated over the remaining life of the unit.
Entergy New Orleans [Member]
Asset Retirement Obligation Disclosure [Text Block]	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. Following is an update to that discussion. In the second quarter 2017, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $35.9 million reduction in its decommissioning cost liability, along with a corresponding reduction in the related asset retirement cost asset that will be depreciated over the remaining life of the unit.
Entergy Texas [Member]
Asset Retirement Obligation Disclosure [Text Block]	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. Following is an update to that discussion. In the second quarter 2017, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $35.9 million reduction in its decommissioning cost liability, along with a corresponding reduction in the related asset retirement cost asset that will be depreciated over the remaining life of the unit.
System Energy [Member]
Asset Retirement Obligation Disclosure [Text Block]	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. Following is an update to that discussion. In the second quarter 2017, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $35.9 million reduction in its decommissioning cost liability, along with a corresponding reduction in the related asset retirement cost asset that will be depreciated over the remaining life of the unit.

Equity (Tables)

Equity (Tables)	6 Months Ended
	Jun. 30, 2017
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, 2017 2016 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $409.9 179.5 $2.28 $567.3 178.8 $3.17 Average dilutive effect of: Stock options 0.2 — 0.2 — Other equity plans 0.5 (0.01 ) 0.5 (0.01 ) Diluted earnings per share $409.9 180.2 $2.27 $567.3 179.5 $3.16 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 2.5 million for the three months ended June 30, 2017 and approximately 4.1 million for the three months ended June 30, 2016 . For the Six Months Ended June 30, 2017 2016 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $492.5 179.4 $2.75 $797.3 178.7 $4.46 Average dilutive effect of: Stock options 0.2 — 0.1 — Other equity plans 0.4 (0.01 ) 0.4 (0.01 ) Diluted earnings per share $492.5 180.0 $2.74 $797.3 179.2 $4.45
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, 2017 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, April 1, 2017 $3,465 ($460,814 ) $467,561 $748 $10,960 Other comprehensive income (loss) before reclassifications 28,057 — 33,870 (748 ) 61,179 Amounts reclassified from accumulated other comprehensive income (loss) (8,108 ) 10,916 (22,174 ) — (19,366 ) Net other comprehensive income (loss) for the period 19,949 10,916 11,696 (748 ) 41,813 Ending balance, June 30, 2017 $23,414 ($449,898 ) $479,257 $— $52,773 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 six months ended June 30, 2017 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Foreign currency translation Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Beginning balance, January 1, 2017 $3,993 ($469,446 ) $429,734 $748 ($34,971 ) Other comprehensive income (loss) before reclassifications 60,665 — 73,742 (748 ) 133,659 Amounts reclassified from accumulated other comprehensive income (loss) (41,244 ) 19,548 (24,219 ) — (45,915 ) Net other comprehensive income (loss) for the period 19,421 19,548 49,523 (748 ) 87,744 Ending balance, June 30, 2017 $23,414 ($449,898 ) $479,257 $— $52,773 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 )
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, 2017 and 2016 are as follows: Amounts reclassified Income Statement Location 2017 2016 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $12,695 $45,975 Competitive business operating revenues Interest rate swaps (219 ) 30 Miscellaneous - net Total realized gain (loss) on cash flow hedges 12,476 46,005 (4,368 ) (16,102 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $8,108 $29,903 Pension and other postretirement liabilities Amortization of prior-service credit $6,564 $7,355 (a) Amortization of loss (21,554 ) (15,177 ) (a) Settlement loss (1,765 ) — (a) Total amortization (16,755 ) (7,822 ) 5,839 2,779 Income taxes Total amortization (net of tax) ($10,916 ) ($5,043 ) Net unrealized investment gain (loss) Realized gain (loss) $43,479 $6,000 Interest and investment income (21,305 ) (2,939 ) Income taxes Total realized investment gain (loss) (net of tax) $22,174 $3,061 Total reclassifications for the period (net of tax) $19,366 $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 six months ended June 30, 2017 and 2016 are as follows: Amounts reclassified from AOCI Income Statement Location 2017 2016 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $63,922 $199,933 Competitive business operating revenues Interest rate swaps (469 ) (370 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 63,453 199,563 (22,209 ) (69,847 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $41,244 $129,716 Pension and other postretirement liabilities Amortization of prior-service credit $13,126 $14,710 (a) Amortization of loss (43,125 ) (30,352 ) (a) Settlement loss (1,765 ) — (a) Total amortization (31,764 ) (15,642 ) 12,216 3,037 Income taxes Total amortization (net of tax) ($19,548 ) ($12,605 ) Net unrealized investment gain (loss) Realized gain (loss) $47,489 $9,850 Interest and investment income (23,270 ) (4,826 ) Income taxes Total realized investment gain (loss) (net of tax) $24,219 $5,024 Total reclassifications for the period (net of tax) $45,915 $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.
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, 2017 and 2016: Pension and Other 2017 2016 (In Thousands) Beginning balance, April 1, ($48,812 ) ($56,675 ) Amounts reclassified from accumulated other (310 ) (230 ) Net other comprehensive income (loss) for the period (310 ) (230 ) Ending balance, June 30, ($49,122 ) ($56,905 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2017 and 2016: Pension and Other 2017 2016 (In Thousands) Beginning balance, January 1, ($48,442 ) ($56,412 ) Amounts reclassified from accumulated other (680 ) (493 ) Net other comprehensive income (loss) for the period (680 ) (493 ) Ending balance, June 30, ($49,122 ) ($56,905 )
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, 2017 and 2016 are as follows: Amounts reclassified Income Statement Location 2017 2016 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,934 $1,947 (a) Amortization of loss (1,332 ) (1,573 ) (a) Total amortization 602 374 (292 ) (144 ) Income taxes Total amortization (net of tax) 310 230 Total reclassifications for the period (net of tax) $310 $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 six months ended June 30, 2017 and 2016 are as follows: Amounts reclassified Income Statement Location 2017 2016 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $3,868 $3,894 (a) Amortization of loss (2,664 ) (3,142 ) (a) Total amortization 1,204 752 (524 ) (259 ) Income taxes Total amortization (net of tax) 680 493 Total reclassifications for the period (net of tax) $680 $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.

Revolving Credit Facilities, 25

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2017
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, 2017 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $225 $6 $3,269
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2017 Letters of Credit Outstanding as of June 30, 2017 Entergy Arkansas April 2018 $20 million (b) 2.48% $— $— Entergy Arkansas August 2021 $150 million (c) 2.48% $— $— Entergy Louisiana August 2021 $350 million (d) 2.48% $— $4.5 million Entergy Mississippi May 2018 $37.5 million (e) 2.73% $— $— Entergy Mississippi May 2018 $35 million (e) 2.73% $— $— Entergy Mississippi May 2018 $20 million (e) 2.73% $— $— Entergy Mississippi May 2018 $10 million (e) 2.73% $— $— Entergy New Orleans November 2018 $25 million (f) 2.70% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.73% $— $13.3 million (a) The interest rate is the rate as of June 30, 2017 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, 2017 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2017 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $36.8 million Entergy Mississippi $40 million 0.70% $7.8 million Entergy New Orleans $15 million 0.75% $5.6 million Entergy Texas $50 million 0.70% $22.3 million (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. See Note 8 to the financial statements for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2017 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $14 Entergy Louisiana $450 $— Entergy Mississippi $175 $56 Entergy New Orleans $100 $— Entergy Texas $200 $39 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 as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2017 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.39% $31.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.12% $15.5 Entergy Louisiana Waterford VIE May 2019 $85 2.38% $70.8 (c) System Energy VIE May 2019 $120 2.42% $103.2 (d) (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) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Arkansas VIE as of June 30, 2017 was $14.7 million . (c) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Louisiana Waterford VIE as of June 30, 2017 was $34.5 million . (d) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for System Energy VIE as of June 30, 2017 was $53.2 million .
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, 2017 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 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 Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million
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, 2017 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,010,668 $15,239,655 Entergy Arkansas $3,064,261 $2,942,288 Entergy Louisiana $6,246,015 $6,484,470 Entergy Mississippi $1,121,356 $1,137,274 Entergy New Orleans $444,159 $467,094 Entergy Texas $1,471,091 $1,560,208 System Energy $551,296 $482,650 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2016 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,832,555 $14,815,535 Entergy Arkansas $2,829,785 $2,623,910 Entergy Louisiana $5,812,791 $5,929,488 Entergy Mississippi $1,120,916 $1,086,203 Entergy New Orleans $448,994 $455,459 Entergy Texas $1,508,407 $1,600,156 System Energy $551,132 $529,520 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2017 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2017 Letters of Credit Outstanding as of June 30, 2017 Entergy Arkansas April 2018 $20 million (b) 2.48% $— $— Entergy Arkansas August 2021 $150 million (c) 2.48% $— $— Entergy Louisiana August 2021 $350 million (d) 2.48% $— $4.5 million Entergy Mississippi May 2018 $37.5 million (e) 2.73% $— $— Entergy Mississippi May 2018 $35 million (e) 2.73% $— $— Entergy Mississippi May 2018 $20 million (e) 2.73% $— $— Entergy Mississippi May 2018 $10 million (e) 2.73% $— $— Entergy New Orleans November 2018 $25 million (f) 2.70% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.73% $— $13.3 million (a) The interest rate is the rate as of June 30, 2017 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, 2017 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2017 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $36.8 million Entergy Mississippi $40 million 0.70% $7.8 million Entergy New Orleans $15 million 0.75% $5.6 million Entergy Texas $50 million 0.70% $22.3 million (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. See Note 8 to the financial statements for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2017 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $14 Entergy Louisiana $450 $— Entergy Mississippi $175 $56 Entergy New Orleans $100 $— Entergy Texas $200 $39 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 as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2017 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.39% $31.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.12% $15.5 Entergy Louisiana Waterford VIE May 2019 $85 2.38% $70.8 (c) System Energy VIE May 2019 $120 2.42% $103.2 (d) (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) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Arkansas VIE as of June 30, 2017 was $14.7 million . (c) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Louisiana Waterford VIE as of June 30, 2017 was $34.5 million . (d) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for System Energy VIE as of June 30, 2017 was $53.2 million .
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, 2017 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 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 Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million
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, 2017 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,010,668 $15,239,655 Entergy Arkansas $3,064,261 $2,942,288 Entergy Louisiana $6,246,015 $6,484,470 Entergy Mississippi $1,121,356 $1,137,274 Entergy New Orleans $444,159 $467,094 Entergy Texas $1,471,091 $1,560,208 System Energy $551,296 $482,650 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2016 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,832,555 $14,815,535 Entergy Arkansas $2,829,785 $2,623,910 Entergy Louisiana $5,812,791 $5,929,488 Entergy Mississippi $1,120,916 $1,086,203 Entergy New Orleans $448,994 $455,459 Entergy Texas $1,508,407 $1,600,156 System Energy $551,132 $529,520 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2017 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2017 Letters of Credit Outstanding as of June 30, 2017 Entergy Arkansas April 2018 $20 million (b) 2.48% $— $— Entergy Arkansas August 2021 $150 million (c) 2.48% $— $— Entergy Louisiana August 2021 $350 million (d) 2.48% $— $4.5 million Entergy Mississippi May 2018 $37.5 million (e) 2.73% $— $— Entergy Mississippi May 2018 $35 million (e) 2.73% $— $— Entergy Mississippi May 2018 $20 million (e) 2.73% $— $— Entergy Mississippi May 2018 $10 million (e) 2.73% $— $— Entergy New Orleans November 2018 $25 million (f) 2.70% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.73% $— $13.3 million (a) The interest rate is the rate as of June 30, 2017 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, 2017 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2017 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $36.8 million Entergy Mississippi $40 million 0.70% $7.8 million Entergy New Orleans $15 million 0.75% $5.6 million Entergy Texas $50 million 0.70% $22.3 million (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. See Note 8 to the financial statements for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2017 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $14 Entergy Louisiana $450 $— Entergy Mississippi $175 $56 Entergy New Orleans $100 $— Entergy Texas $200 $39 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 as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2017 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.39% $31.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.12% $15.5 Entergy Louisiana Waterford VIE May 2019 $85 2.38% $70.8 (c) System Energy VIE May 2019 $120 2.42% $103.2 (d) (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) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Arkansas VIE as of June 30, 2017 was $14.7 million . (c) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Louisiana Waterford VIE as of June 30, 2017 was $34.5 million . (d) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for System Energy VIE as of June 30, 2017 was $53.2 million .
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, 2017 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 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 Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million
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, 2017 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,010,668 $15,239,655 Entergy Arkansas $3,064,261 $2,942,288 Entergy Louisiana $6,246,015 $6,484,470 Entergy Mississippi $1,121,356 $1,137,274 Entergy New Orleans $444,159 $467,094 Entergy Texas $1,471,091 $1,560,208 System Energy $551,296 $482,650 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2016 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,832,555 $14,815,535 Entergy Arkansas $2,829,785 $2,623,910 Entergy Louisiana $5,812,791 $5,929,488 Entergy Mississippi $1,120,916 $1,086,203 Entergy New Orleans $448,994 $455,459 Entergy Texas $1,508,407 $1,600,156 System Energy $551,132 $529,520 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2017 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2017 Letters of Credit Outstanding as of June 30, 2017 Entergy Arkansas April 2018 $20 million (b) 2.48% $— $— Entergy Arkansas August 2021 $150 million (c) 2.48% $— $— Entergy Louisiana August 2021 $350 million (d) 2.48% $— $4.5 million Entergy Mississippi May 2018 $37.5 million (e) 2.73% $— $— Entergy Mississippi May 2018 $35 million (e) 2.73% $— $— Entergy Mississippi May 2018 $20 million (e) 2.73% $— $— Entergy Mississippi May 2018 $10 million (e) 2.73% $— $— Entergy New Orleans November 2018 $25 million (f) 2.70% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.73% $— $13.3 million (a) The interest rate is the rate as of June 30, 2017 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, 2017 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2017 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $36.8 million Entergy Mississippi $40 million 0.70% $7.8 million Entergy New Orleans $15 million 0.75% $5.6 million Entergy Texas $50 million 0.70% $22.3 million (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. See Note 8 to the financial statements for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2017 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $14 Entergy Louisiana $450 $— Entergy Mississippi $175 $56 Entergy New Orleans $100 $— Entergy Texas $200 $39 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, 2017 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,010,668 $15,239,655 Entergy Arkansas $3,064,261 $2,942,288 Entergy Louisiana $6,246,015 $6,484,470 Entergy Mississippi $1,121,356 $1,137,274 Entergy New Orleans $444,159 $467,094 Entergy Texas $1,471,091 $1,560,208 System Energy $551,296 $482,650 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2016 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,832,555 $14,815,535 Entergy Arkansas $2,829,785 $2,623,910 Entergy Louisiana $5,812,791 $5,929,488 Entergy Mississippi $1,120,916 $1,086,203 Entergy New Orleans $448,994 $455,459 Entergy Texas $1,508,407 $1,600,156 System Energy $551,132 $529,520 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2017 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2017 Letters of Credit Outstanding as of June 30, 2017 Entergy Arkansas April 2018 $20 million (b) 2.48% $— $— Entergy Arkansas August 2021 $150 million (c) 2.48% $— $— Entergy Louisiana August 2021 $350 million (d) 2.48% $— $4.5 million Entergy Mississippi May 2018 $37.5 million (e) 2.73% $— $— Entergy Mississippi May 2018 $35 million (e) 2.73% $— $— Entergy Mississippi May 2018 $20 million (e) 2.73% $— $— Entergy Mississippi May 2018 $10 million (e) 2.73% $— $— Entergy New Orleans November 2018 $25 million (f) 2.70% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.73% $— $13.3 million (a) The interest rate is the rate as of June 30, 2017 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, 2017 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2017 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $36.8 million Entergy Mississippi $40 million 0.70% $7.8 million Entergy New Orleans $15 million 0.75% $5.6 million Entergy Texas $50 million 0.70% $22.3 million (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. See Note 8 to the financial statements for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2017 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $14 Entergy Louisiana $450 $— Entergy Mississippi $175 $56 Entergy New Orleans $100 $— Entergy Texas $200 $39 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, 2017 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,010,668 $15,239,655 Entergy Arkansas $3,064,261 $2,942,288 Entergy Louisiana $6,246,015 $6,484,470 Entergy Mississippi $1,121,356 $1,137,274 Entergy New Orleans $444,159 $467,094 Entergy Texas $1,471,091 $1,560,208 System Energy $551,296 $482,650 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2016 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,832,555 $14,815,535 Entergy Arkansas $2,829,785 $2,623,910 Entergy Louisiana $5,812,791 $5,929,488 Entergy Mississippi $1,120,916 $1,086,203 Entergy New Orleans $448,994 $455,459 Entergy Texas $1,508,407 $1,600,156 System Energy $551,132 $529,520 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2017 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of June 30, 2017 Letters of Credit Outstanding as of June 30, 2017 Entergy Arkansas April 2018 $20 million (b) 2.48% $— $— Entergy Arkansas August 2021 $150 million (c) 2.48% $— $— Entergy Louisiana August 2021 $350 million (d) 2.48% $— $4.5 million Entergy Mississippi May 2018 $37.5 million (e) 2.73% $— $— Entergy Mississippi May 2018 $35 million (e) 2.73% $— $— Entergy Mississippi May 2018 $20 million (e) 2.73% $— $— Entergy Mississippi May 2018 $10 million (e) 2.73% $— $— Entergy New Orleans November 2018 $25 million (f) 2.70% $— $0.8 million Entergy Texas August 2021 $150 million (g) 2.73% $— $13.3 million (a) The interest rate is the rate as of June 30, 2017 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, 2017 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of June 30, 2017 (a) Entergy Arkansas $25 million 0.70% $1.0 million Entergy Louisiana $125 million 0.70% $36.8 million Entergy Mississippi $40 million 0.70% $7.8 million Entergy New Orleans $15 million 0.75% $5.6 million Entergy Texas $50 million 0.70% $22.3 million (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. See Note 8 to the financial statements for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2017 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $14 Entergy Louisiana $450 $— Entergy Mississippi $175 $56 Entergy New Orleans $100 $— Entergy Texas $200 $39 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, 2017 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,010,668 $15,239,655 Entergy Arkansas $3,064,261 $2,942,288 Entergy Louisiana $6,246,015 $6,484,470 Entergy Mississippi $1,121,356 $1,137,274 Entergy New Orleans $444,159 $467,094 Entergy Texas $1,471,091 $1,560,208 System Energy $551,296 $482,650 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2016 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,832,555 $14,815,535 Entergy Arkansas $2,829,785 $2,623,910 Entergy Louisiana $5,812,791 $5,929,488 Entergy Mississippi $1,120,916 $1,086,203 Entergy New Orleans $448,994 $455,459 Entergy Texas $1,508,407 $1,600,156 System Energy $551,132 $529,520 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2017 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $14 Entergy Louisiana $450 $— Entergy Mississippi $175 $56 Entergy New Orleans $100 $— Entergy Texas $200 $39 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 as of June 30, 2017 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of June 30, 2017 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 2.39% $31.4 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.12% $15.5 Entergy Louisiana Waterford VIE May 2019 $85 2.38% $70.8 (c) System Energy VIE May 2019 $120 2.42% $103.2 (d) (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) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Arkansas VIE as of June 30, 2017 was $14.7 million . (c) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Louisiana Waterford VIE as of June 30, 2017 was $34.5 million . (d) Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for System Energy VIE as of June 30, 2017 was $53.2 million .
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, 2017 as follows: Company Description Amount Entergy Arkansas VIE 2.62% Series K due December 2017 $60 million Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 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 Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million
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, 2017 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,010,668 $15,239,655 Entergy Arkansas $3,064,261 $2,942,288 Entergy Louisiana $6,246,015 $6,484,470 Entergy Mississippi $1,121,356 $1,137,274 Entergy New Orleans $444,159 $467,094 Entergy Texas $1,471,091 $1,560,208 System Energy $551,296 $482,650 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein 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, 2016 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $14,832,555 $14,815,535 Entergy Arkansas $2,829,785 $2,623,910 Entergy Louisiana $5,812,791 $5,929,488 Entergy Mississippi $1,120,916 $1,086,203 Entergy New Orleans $448,994 $455,459 Entergy Texas $1,508,407 $1,600,156 System Energy $551,132 $529,520 (a) The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein and are based on prices derived from inputs such as benchmark yields and reported trades.

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2017
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, 2017 and 2016 : 2017 2016 (In Millions) Compensation expense included in Entergy’s net income $1.1 $1.1 Tax benefit recognized in Entergy’s net income $0.4 $0.4 Compensation cost capitalized as part of fixed assets and inventory $0.2 $0.2 The following table includes financial information for outstanding stock options for the six months ended June 30, 2017 and 2016 : 2017 2016 (In Millions) Compensation expense included in Entergy’s net income $2.2 $2.2 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, 2017 and 2016 : 2017 2016 (In Millions) Compensation expense included in Entergy’s net income $8.2 $8.5 Tax benefit recognized in Entergy’s net income $3.2 $3.3 Compensation cost capitalized as part of fixed assets and inventory $2.2 $1.9 The following table includes financial information for other outstanding equity awards for the six months ended June 30, 2017 and 2016 : 2017 2016 (In Millions) Compensation expense included in Entergy’s net income $16.4 $16.9 Tax benefit recognized in Entergy’s net income $6.3 $6.5 Compensation cost capitalized as part of fixed assets and inventory $4.2 $3.7

Retirement And Other Postreti27

Retirement And Other Postretirement Benefits (Tables)	6 Months Ended
	Jun. 30, 2017
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 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($89 ) $6,564 Amortization of loss (18,450 ) (2,202 ) (902 ) (21,554 ) Settlement loss — — (1,765 ) (1,765 ) ($18,515 ) $4,516 ($2,756 ) ($16,755 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 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 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, 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($130 ) $13,435 ($179 ) $13,126 Amortization of loss (36,899 ) (4,404 ) (1,822 ) (43,125 ) Settlement loss — — (1,765 ) (1,765 ) ($37,029 ) $9,031 ($3,766 ) ($31,764 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of loss (1,730 ) (930 ) (4 ) (2,664 ) ($1,730 ) $2,938 ($4 ) $1,204 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
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 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $33,410 $35,811 Interest cost on projected benefit obligation 65,206 65,403 Expected return on assets (102,056 ) (97,366 ) Amortization of prior service cost 65 270 Amortization of loss 56,930 48,824 Net pension costs $53,555 $52,942 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $66,820 $71,622 Interest cost on projected benefit obligation 130,412 130,806 Expected return on assets (204,112 ) (194,732 ) Amortization of prior service cost 130 540 Amortization of loss 113,860 97,648 Net pension costs $107,110 $105,884
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 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $6,729 $8,073 Interest cost on accumulated postretirement benefit obligation (APBO) 13,960 14,083 Expected return on assets (9,408 ) (10,455 ) Amortization of prior service credit (10,356 ) (11,373 ) Amortization of loss 5,476 4,554 Net other postretirement benefit cost $6,401 $4,882 Entergy’s other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2017 and 2016, included the following components: 2017 2016 (In Thousands) Service cost - benefits earned during the period $13,458 $16,146 Interest cost on accumulated postretirement benefit obligation (APBO) 27,920 28,166 Expected return on assets (18,816 ) (20,910 ) Amortization of prior service credit (20,712 ) (22,746 ) Amortization of loss 10,952 9,108 Net other postretirement benefit cost $12,802 $9,764
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 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,180 $13,850 $2,944 $1,250 $2,728 $3,072 Interest cost on projects benefit obligation 25,888 29,618 7,464 3,582 6,784 6,182 Expected return on assets (40,854 ) (46,034 ) (12,262 ) (5,600 ) (12,360 ) (9,326 ) Amortization of loss 23,280 24,708 6,106 3,316 4,620 5,928 Net pension cost $18,494 $22,142 $4,252 $2,548 $1,772 $5,856 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
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2017 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2017 pension contributions $79,495 $87,923 $19,146 $9,920 $17,064 $18,180 Pension contributions made through June 2017 $34,507 $37,519 $8,251 $4,361 $7,227 $8,182 Remaining estimated pension contributions to be made in 2017 $44,988 $50,404 $10,895 $5,559 $9,837 $9,998
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 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,726 $3,186 $580 $284 $744 $640 Interest cost on APBO 4,510 6,050 1,380 938 2,248 1,118 Expected return on assets (7,918 ) — (2,400 ) (2,318 ) (4,360 ) (1,434 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of loss 2,230 930 838 210 1,652 780 Net other postretirement benefit cost ($2,008 ) $6,298 ($514 ) ($1,258 ) ($874 ) $348 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 )
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 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $267 $47 $63 $18 $126 2016 $106 $59 $59 $16 $127 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $372 $96 $127 $36 $253 2016 $212 $118 $118 $32 $254
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 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,718 ($89 ) $6,564 Amortization of loss (18,450 ) (2,202 ) (902 ) (21,554 ) Settlement loss — — (1,765 ) (1,765 ) ($18,515 ) $4,516 ($2,756 ) ($16,755 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 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 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, 2017 and 2016: 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($130 ) $13,435 ($179 ) $13,126 Amortization of loss (36,899 ) (4,404 ) (1,822 ) (43,125 ) Settlement loss — — (1,765 ) (1,765 ) ($37,029 ) $9,031 ($3,766 ) ($31,764 ) Entergy Louisiana Amortization of prior service credit $— $3,868 $— $3,868 Amortization of loss (1,730 ) (930 ) (4 ) (2,664 ) ($1,730 ) $2,938 ($4 ) $1,204 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
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 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,180 $13,850 $2,944 $1,250 $2,728 $3,072 Interest cost on projects benefit obligation 25,888 29,618 7,464 3,582 6,784 6,182 Expected return on assets (40,854 ) (46,034 ) (12,262 ) (5,600 ) (12,360 ) (9,326 ) Amortization of loss 23,280 24,708 6,106 3,316 4,620 5,928 Net pension cost $18,494 $22,142 $4,252 $2,548 $1,772 $5,856 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
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2017 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2017 pension contributions $79,495 $87,923 $19,146 $9,920 $17,064 $18,180 Pension contributions made through June 2017 $34,507 $37,519 $8,251 $4,361 $7,227 $8,182 Remaining estimated pension contributions to be made in 2017 $44,988 $50,404 $10,895 $5,559 $9,837 $9,998
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 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,726 $3,186 $580 $284 $744 $640 Interest cost on APBO 4,510 6,050 1,380 938 2,248 1,118 Expected return on assets (7,918 ) — (2,400 ) (2,318 ) (4,360 ) (1,434 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of loss 2,230 930 838 210 1,652 780 Net other postretirement benefit cost ($2,008 ) $6,298 ($514 ) ($1,258 ) ($874 ) $348 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 )
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 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $267 $47 $63 $18 $126 2016 $106 $59 $59 $16 $127 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $372 $96 $127 $36 $253 2016 $212 $118 $118 $32 $254
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 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,180 $13,850 $2,944 $1,250 $2,728 $3,072 Interest cost on projects benefit obligation 25,888 29,618 7,464 3,582 6,784 6,182 Expected return on assets (40,854 ) (46,034 ) (12,262 ) (5,600 ) (12,360 ) (9,326 ) Amortization of loss 23,280 24,708 6,106 3,316 4,620 5,928 Net pension cost $18,494 $22,142 $4,252 $2,548 $1,772 $5,856 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
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2017 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2017 pension contributions $79,495 $87,923 $19,146 $9,920 $17,064 $18,180 Pension contributions made through June 2017 $34,507 $37,519 $8,251 $4,361 $7,227 $8,182 Remaining estimated pension contributions to be made in 2017 $44,988 $50,404 $10,895 $5,559 $9,837 $9,998
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 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,726 $3,186 $580 $284 $744 $640 Interest cost on APBO 4,510 6,050 1,380 938 2,248 1,118 Expected return on assets (7,918 ) — (2,400 ) (2,318 ) (4,360 ) (1,434 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of loss 2,230 930 838 210 1,652 780 Net other postretirement benefit cost ($2,008 ) $6,298 ($514 ) ($1,258 ) ($874 ) $348 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 )
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 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $267 $47 $63 $18 $126 2016 $106 $59 $59 $16 $127 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $372 $96 $127 $36 $253 2016 $212 $118 $118 $32 $254
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 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,180 $13,850 $2,944 $1,250 $2,728 $3,072 Interest cost on projects benefit obligation 25,888 29,618 7,464 3,582 6,784 6,182 Expected return on assets (40,854 ) (46,034 ) (12,262 ) (5,600 ) (12,360 ) (9,326 ) Amortization of loss 23,280 24,708 6,106 3,316 4,620 5,928 Net pension cost $18,494 $22,142 $4,252 $2,548 $1,772 $5,856 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
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2017 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2017 pension contributions $79,495 $87,923 $19,146 $9,920 $17,064 $18,180 Pension contributions made through June 2017 $34,507 $37,519 $8,251 $4,361 $7,227 $8,182 Remaining estimated pension contributions to be made in 2017 $44,988 $50,404 $10,895 $5,559 $9,837 $9,998
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 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,726 $3,186 $580 $284 $744 $640 Interest cost on APBO 4,510 6,050 1,380 938 2,248 1,118 Expected return on assets (7,918 ) — (2,400 ) (2,318 ) (4,360 ) (1,434 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of loss 2,230 930 838 210 1,652 780 Net other postretirement benefit cost ($2,008 ) $6,298 ($514 ) ($1,258 ) ($874 ) $348 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 )
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 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $267 $47 $63 $18 $126 2016 $106 $59 $59 $16 $127 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $372 $96 $127 $36 $253 2016 $212 $118 $118 $32 $254
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 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,180 $13,850 $2,944 $1,250 $2,728 $3,072 Interest cost on projects benefit obligation 25,888 29,618 7,464 3,582 6,784 6,182 Expected return on assets (40,854 ) (46,034 ) (12,262 ) (5,600 ) (12,360 ) (9,326 ) Amortization of loss 23,280 24,708 6,106 3,316 4,620 5,928 Net pension cost $18,494 $22,142 $4,252 $2,548 $1,772 $5,856 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
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2017 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2017 pension contributions $79,495 $87,923 $19,146 $9,920 $17,064 $18,180 Pension contributions made through June 2017 $34,507 $37,519 $8,251 $4,361 $7,227 $8,182 Remaining estimated pension contributions to be made in 2017 $44,988 $50,404 $10,895 $5,559 $9,837 $9,998
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 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,726 $3,186 $580 $284 $744 $640 Interest cost on APBO 4,510 6,050 1,380 938 2,248 1,118 Expected return on assets (7,918 ) — (2,400 ) (2,318 ) (4,360 ) (1,434 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of loss 2,230 930 838 210 1,652 780 Net other postretirement benefit cost ($2,008 ) $6,298 ($514 ) ($1,258 ) ($874 ) $348 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 )
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 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $267 $47 $63 $18 $126 2016 $106 $59 $59 $16 $127 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2017 and 2016: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2017 $372 $96 $127 $36 $253 2016 $212 $118 $118 $32 $254
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 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,181 $7,049 $1,562 $656 $1,416 $1,566 Interest cost on projected benefit obligation 13,055 14,870 3,811 1,814 3,557 2,992 Expected return on assets (19,772 ) (22,096 ) (5,981 ) (2,687 ) (6,062 ) (4,459 ) Amortization of loss 10,936 11,946 2,985 1,615 2,340 2,604 Net pension cost $9,400 $11,769 $2,377 $1,398 $1,251 $2,703 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $10,180 $13,850 $2,944 $1,250 $2,728 $3,072 Interest cost on projects benefit obligation 25,888 29,618 7,464 3,582 6,784 6,182 Expected return on assets (40,854 ) (46,034 ) (12,262 ) (5,600 ) (12,360 ) (9,326 ) Amortization of loss 23,280 24,708 6,106 3,316 4,620 5,928 Net pension cost $18,494 $22,142 $4,252 $2,548 $1,772 $5,856 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
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2017 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2017 pension contributions $79,495 $87,923 $19,146 $9,920 $17,064 $18,180 Pension contributions made through June 2017 $34,507 $37,519 $8,251 $4,361 $7,227 $8,182 Remaining estimated pension contributions to be made in 2017 $44,988 $50,404 $10,895 $5,559 $9,837 $9,998
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 2017 and 2016, included the following components: 2017 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 2016 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $978 $1,869 $386 $156 $398 $334 Interest cost on APBO 2,324 3,260 709 448 1,039 529 Expected return on assets (4,464 ) — (1,379 ) (1,154 ) (2,394 ) (814 ) Amortization of prior service credit (1,368 ) (1,947 ) (234 ) (186 ) (681 ) (393 ) Amortization of loss 1,064 732 223 37 537 287 Net other postretirement benefit cost ($1,466 ) $3,914 ($295 ) ($699 ) ($1,101 ) ($57 ) The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the six months ended June 30, 2017 and 2016, included the following components: 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $1,726 $3,186 $580 $284 $744 $640 Interest cost on APBO 4,510 6,050 1,380 938 2,248 1,118 Expected return on assets (7,918 ) — (2,400 ) (2,318 ) (4,360 ) (1,434 ) Amortization of prior service credit (2,556 ) (3,868 ) (912 ) (372 ) (1,158 ) (756 ) Amortization of loss 2,230 930 838 210 1,652 780 Net other postretirement benefit cost ($2,008 ) $6,298 ($514 ) ($1,258 ) ($874 ) $348 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 )

Business Segment Information (T

Business Segment Information (Tables)	6 Months Ended
	Jun. 30, 2017
Segment Financial Information	Entergy’s segment financial information for the second quarters of 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $2,301,332 $317,255 $— ($37 ) $2,618,550 Income taxes $130,851 ($454,944 ) ($13,019 ) $— ($337,112 ) Consolidated net income (loss) $246,382 $223,886 ($25,001 ) ($31,899 ) $413,368 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 Entergy’s segment financial information for the six months ended June 30, 2017 and 2016 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2017 Operating revenues $4,336,444 $870,622 $— ($58 ) $5,207,008 Income taxes $229,343 ($533,281 ) ($25,412 ) $— ($329,350 ) Consolidated net income (loss) $414,005 $196,689 ($47,477 ) ($63,797 ) $499,420 Total assets as of June 30, 2017 $42,263,832 $5,627,284 $1,165,157 ($3,049,236 ) $46,007,037 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 December 31, 2016 $41,098,751 $6,696,038 $1,283,816 ($3,174,171 ) $45,904,434 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.
Restructuring and Related Costs [Table Text Block]	Additional restructuring charges for the second quarter 2017 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of April 1, 2017 $94 $21 $115 Restructuring costs accrued 42 — 42 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $194 million of impairment charges in the second quarter 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Additional restructuring charges for the six months ended June 30, 2017 were comprised of the following: Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, 2017 $70 $21 $91 Restructuring costs accrued 66 — 66 Cash paid out 100 — 100 Balance as of June 30, 2017 $36 $21 $57 In addition, Entergy incurred $405 million of impairment charges in the six months ended June 30, 2017 related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets.

Risk Management And Fair Valu29

Risk Management And Fair Values (Tables)	6 Months Ended
	Jun. 30, 2017
Fair Values Of Derivative Instruments	The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of June 30, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location 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) $40 ($23) $17 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($9) $10 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $15 ($15) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $12 ($10) $2 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $16 ($3) $13 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $2 ($2) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $61 ($4) $57 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities(current portion) $10 ($10) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $1 ($1) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $5 $— $5 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2016 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Fair Value (a) Offset (b) Net (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $25 ($14) $11 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $6 ($6) $— Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $11 ($10) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $16 ($7) $9 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $18 ($13) $5 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Natural gas swaps Prepayments and other $13 $— $13 Utility Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $18 ($17) $1 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $4 ($4) $— Entergy Wholesale Commodities (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $3 million held as of June 30, 2017 and $2 million posted as of December 31, 2016. Also excludes $19 million in letters of credit held as of June 30, 2017.
Derivative Instruments Designated As Cash Flow Hedges On Consolidated Statements Of Income	The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2017 Electricity swaps and options $43 Competitive businesses operating revenues $13 2016 Electricity swaps and options ($53) Competitive businesses operating revenues $46 (a) Before taxes of $4 million and $16 million for the three months ended June 30, 2017 and 2016, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain Income Statement location Amount of gain (In Millions) (In Millions) 2017 Electricity swaps and options $93 Competitive businesses operating revenues $64 2016 Electricity swaps and options $86 Competitive businesses operating revenues $200 (a) Before taxes of $22 million and $70 million for the six months ended June 30, 2017 and 2016, respectively
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2017 and 2016 are as follows: Instrument Amount of loss recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) FTRs $— Purchased power expense (b) $44 Electricity swaps and options ($5) (c) Competitive business operating revenues $— 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 ($10) (c) Competitive business operating revenues ($6) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($16) Financial transmission rights $— Purchased power expense (b) $75 Electricity swaps and options $4 (c) Competitive business operating revenues $— 2016 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($30) Financial transmission rights $— Purchased power expense (b) $59 Electricity swaps and options $15 (c) Competitive business operating revenues ($9) (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain (loss) recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items.
Assets and liabilities at fair value on a recurring basis	The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2017 and December 31, 2016 . The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $867 $— $— $867 Decommissioning trust funds (a): Equity securities 469 — — 469 Debt securities 1,032 1,376 — 2,408 Common trusts (b) 3,920 Power contracts — — 40 40 Securitization recovery trust account 36 — — 36 Escrow accounts 416 — — 416 Financial transmission rights — — 57 57 $2,820 $1,376 $97 $8,213 Liabilities: Power contracts $— $— $2 $2 Gas hedge contracts 5 — — 5 $5 $— $2 $7 2016 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,058 $— $— $1,058 Decommissioning trust funds (a): Equity securities 480 — — 480 Debt securities 985 1,228 — 2,213 Common trusts (b) 3,031 Power contracts — — 16 16 Securitization recovery trust account 46 — — 46 Escrow accounts 433 — — 433 Gas hedge contracts 13 — — 13 Financial transmission rights — — 21 21 $3,015 $1,228 $37 $7,311 Liabilities: Power contracts $— $— $11 $11 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2017 and 2016 : 2017 2016 Power Contracts Financial transmission rights Power Contracts Financial transmission rights (In Millions) Balance as of April 1, $5 $8 $183 $9 Total gains (losses) for the period (a) Included in earnings 4 — (9 ) — Included in OCI 43 — (53 ) — Included as a regulatory liability/asset — 31 — 20 Issuances of FTRs — 62 — 55 Purchases — — — — Settlements (14 ) (44 ) (55 ) (38 ) Balance as of June 30, $38 $57 $66 $46 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($0.1) million for the three months ended June 30, 2017 and ($6) million for the three months ended June 30, 2016. 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, 2017 and 2016 : 2017 2016 Power Contracts Financial transmission rights Power Contracts Financial transmission rights (In Millions) Balance as of January 1, $5 $21 $189 $23 Total gains (losses) for the period (a) Included in earnings 4 — (9 ) — Included in OCI 93 — 86 — Included as a regulatory liability/asset — 48 — 27 Issuances of financial transmission rights — 62 — 55 Purchases — — — — Settlements (64 ) (74 ) (200 ) (59 ) Balance as of June 30, $38 $57 $66 $46 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is $0.3 million for the six months ended June 30, 2017. 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.
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, 2017 : Transaction Type Fair Value as of June 30, 2017 Significant Unobservable Inputs Range from Average % Effect on Fair Value (In Millions) (In Millions) Power contracts - electricity swaps $38 Unit contingent discount +/- 4% $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, 2017 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $8.3 Entergy Arkansas Financial transmission rights Prepayments and other $28.3 Entergy Louisiana Financial transmission rights Prepayments and other $9.1 Entergy Mississippi Financial transmission rights Prepayments and other $5.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.5 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $4.5 Entergy Louisiana Natural gas swaps Other current liabilities $0.8 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $10.9 Entergy Louisiana Natural gas swaps Prepayments and other $2.3 Entergy Mississippi Natural gas swaps Prepayments and other $0.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.5 Entergy Louisiana Financial transmission rights Prepayments and other $3.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 Entergy New Orleans Financial transmission rights Prepayments and other $3.1 Entergy Texas (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. As of December 31, 2016, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi.
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, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.4) (a) Entergy Mississippi FTRs Purchased power expense $10.5 (b) Entergy Arkansas FTRs Purchased power expense $14.3 (b) Entergy Louisiana FTRs Purchased power expense $8.5 (b) Entergy Mississippi FTRs Purchased power expense $3.4 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 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 The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $15.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $29.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $11.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $12.1 (b) Entergy Texas 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 Financial transmission rights Purchased power expense $13.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $32.1 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $6.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Assets and liabilities at fair value on a recurring basis	Entergy Arkansas 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Decommissioning trust funds (a): Equity securities $10.7 $— $— $10.7 Debt securities 129.7 198.3 — 328.0 Common trusts (b) 545.6 Securitization recovery trust account 3.6 — — 3.6 Escrow accounts 4.7 — — 4.7 Financial transmission rights — — 8.3 8.3 $148.7 $198.3 $8.3 $900.9 2016 Level 1 Level 2 Level 3 Total (In Millions) Assets: Decommissioning trust funds (a): Equity securities $3.6 $— $— $3.6 Debt securities 112.5 196.8 — 309.3 Common trusts (b) 521.8 Securitization recovery trust account 4.1 — — 4.1 Escrow accounts 7.1 — — 7.1 Financial transmission rights — — 5.4 5.4 $127.3 $196.8 $5.4 $851.3
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, 2017. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $0.9 $4.1 $1.3 $0.5 $1.0 Issuances of FTRs 8.9 31.0 9.6 5.0 7.1 Gains included as a regulatory liability/asset 9.0 7.5 6.7 3.1 4.3 Settlements (10.5 ) (14.3 ) (8.5 ) (3.4 ) (6.9 ) Balance as of June 30, $8.3 $28.3 $9.1 $5.2 $5.5 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 Entergy Entergy Entergy Entergy (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 six months ended June 30, 2017 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $5.4 $8.5 $3.2 $1.1 $3.1 Issuances of FTRs 8.9 31.0 9.6 5.0 7.1 Gains included as a regulatory liability/asset 9.1 18.3 7.9 4.8 7.4 Settlements (15.1 ) (29.5 ) (11.6 ) (5.7 ) (12.1 ) Balance as of June 30, $8.3 $28.3 $9.1 $5.2 $5.5 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
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, 2017 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $8.3 Entergy Arkansas Financial transmission rights Prepayments and other $28.3 Entergy Louisiana Financial transmission rights Prepayments and other $9.1 Entergy Mississippi Financial transmission rights Prepayments and other $5.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.5 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $4.5 Entergy Louisiana Natural gas swaps Other current liabilities $0.8 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $10.9 Entergy Louisiana Natural gas swaps Prepayments and other $2.3 Entergy Mississippi Natural gas swaps Prepayments and other $0.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.5 Entergy Louisiana Financial transmission rights Prepayments and other $3.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 Entergy New Orleans Financial transmission rights Prepayments and other $3.1 Entergy Texas (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. As of December 31, 2016, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi.
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, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.4) (a) Entergy Mississippi FTRs Purchased power expense $10.5 (b) Entergy Arkansas FTRs Purchased power expense $14.3 (b) Entergy Louisiana FTRs Purchased power expense $8.5 (b) Entergy Mississippi FTRs Purchased power expense $3.4 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 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 The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $15.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $29.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $11.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $12.1 (b) Entergy Texas 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 Financial transmission rights Purchased power expense $13.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $32.1 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $6.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Assets and liabilities at fair value on a recurring basis	Entergy Louisiana 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $211.9 $— $— $211.9 Decommissioning trust funds (a): Equity securities 11.2 — — 11.2 Debt securities 137.5 326.6 — 464.1 Common trusts (b) 745.4 Escrow accounts 292.9 — — 292.9 Securitization recovery trust account 2.8 — — 2.8 Financial transmission rights — — 28.3 28.3 $656.3 $326.6 $28.3 $1,756.6 Liabilities: Gas hedge contracts $4.5 $— $— $4.5 2016 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $163.9 $— $— $163.9 Decommissioning trust funds (a): Equity securities 13.9 — — 13.9 Debt securities 132.3 292.5 — 424.8 Common trusts (b) 702.0 Escrow accounts 305.7 — — 305.7 Securitization recovery trust account 2.8 — — 2.8 Gas hedge contracts 10.9 — — 10.9 Financial transmission rights — — 8.5 8.5 $629.5 $292.5 $8.5 $1,632.5
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, 2017. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $0.9 $4.1 $1.3 $0.5 $1.0 Issuances of FTRs 8.9 31.0 9.6 5.0 7.1 Gains included as a regulatory liability/asset 9.0 7.5 6.7 3.1 4.3 Settlements (10.5 ) (14.3 ) (8.5 ) (3.4 ) (6.9 ) Balance as of June 30, $8.3 $28.3 $9.1 $5.2 $5.5 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 Entergy Entergy Entergy Entergy (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 six months ended June 30, 2017 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $5.4 $8.5 $3.2 $1.1 $3.1 Issuances of FTRs 8.9 31.0 9.6 5.0 7.1 Gains included as a regulatory liability/asset 9.1 18.3 7.9 4.8 7.4 Settlements (15.1 ) (29.5 ) (11.6 ) (5.7 ) (12.1 ) Balance as of June 30, $8.3 $28.3 $9.1 $5.2 $5.5 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
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, 2017 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $8.3 Entergy Arkansas Financial transmission rights Prepayments and other $28.3 Entergy Louisiana Financial transmission rights Prepayments and other $9.1 Entergy Mississippi Financial transmission rights Prepayments and other $5.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.5 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $4.5 Entergy Louisiana Natural gas swaps Other current liabilities $0.8 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $10.9 Entergy Louisiana Natural gas swaps Prepayments and other $2.3 Entergy Mississippi Natural gas swaps Prepayments and other $0.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.5 Entergy Louisiana Financial transmission rights Prepayments and other $3.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 Entergy New Orleans Financial transmission rights Prepayments and other $3.1 Entergy Texas (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. As of December 31, 2016, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi.
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, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.4) (a) Entergy Mississippi FTRs Purchased power expense $10.5 (b) Entergy Arkansas FTRs Purchased power expense $14.3 (b) Entergy Louisiana FTRs Purchased power expense $8.5 (b) Entergy Mississippi FTRs Purchased power expense $3.4 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 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 The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $15.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $29.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $11.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $12.1 (b) Entergy Texas 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 Financial transmission rights Purchased power expense $13.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $32.1 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $6.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Assets and liabilities at fair value on a recurring basis	Entergy Mississippi 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Escrow accounts $31.9 $— $— $31.9 Financial transmission rights — — 9.1 9.1 $31.9 $— $9.1 $41.0 Liabilities: Gas hedge contracts $0.8 $— $— $0.8 2016 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $76.8 $— $— $76.8 Escrow accounts 31.8 — — 31.8 Gas hedge contracts 2.3 — — 2.3 Financial transmission rights — — 3.2 3.2 $110.9 $— $3.2 $114.1
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2017. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $0.9 $4.1 $1.3 $0.5 $1.0 Issuances of FTRs 8.9 31.0 9.6 5.0 7.1 Gains included as a regulatory liability/asset 9.0 7.5 6.7 3.1 4.3 Settlements (10.5 ) (14.3 ) (8.5 ) (3.4 ) (6.9 ) Balance as of June 30, $8.3 $28.3 $9.1 $5.2 $5.5 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 Entergy Entergy Entergy Entergy (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 six months ended June 30, 2017 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $5.4 $8.5 $3.2 $1.1 $3.1 Issuances of FTRs 8.9 31.0 9.6 5.0 7.1 Gains included as a regulatory liability/asset 9.1 18.3 7.9 4.8 7.4 Settlements (15.1 ) (29.5 ) (11.6 ) (5.7 ) (12.1 ) Balance as of June 30, $8.3 $28.3 $9.1 $5.2 $5.5 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
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, 2017 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $8.3 Entergy Arkansas Financial transmission rights Prepayments and other $28.3 Entergy Louisiana Financial transmission rights Prepayments and other $9.1 Entergy Mississippi Financial transmission rights Prepayments and other $5.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.5 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $4.5 Entergy Louisiana Natural gas swaps Other current liabilities $0.8 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $10.9 Entergy Louisiana Natural gas swaps Prepayments and other $2.3 Entergy Mississippi Natural gas swaps Prepayments and other $0.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.5 Entergy Louisiana Financial transmission rights Prepayments and other $3.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 Entergy New Orleans Financial transmission rights Prepayments and other $3.1 Entergy Texas (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. As of December 31, 2016, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi.
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, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.4) (a) Entergy Mississippi FTRs Purchased power expense $10.5 (b) Entergy Arkansas FTRs Purchased power expense $14.3 (b) Entergy Louisiana FTRs Purchased power expense $8.5 (b) Entergy Mississippi FTRs Purchased power expense $3.4 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 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 The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $15.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $29.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $11.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $12.1 (b) Entergy Texas 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 Financial transmission rights Purchased power expense $13.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $32.1 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $6.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Assets and liabilities at fair value on a recurring basis	Entergy New Orleans 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $60.7 $— $— $60.7 Securitization recovery trust account 1.1 — — 1.1 Escrow accounts 86.4 — — 86.4 Financial transmission rights — — 5.2 5.2 $148.2 $— $5.2 $153.4 2016 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $103.0 $— $— $103.0 Securitization recovery trust account 1.7 — — 1.7 Escrow accounts 88.6 — — 88.6 Gas hedge contracts 0.2 — — 0.2 Financial transmission rights — — 1.1 1.1 $193.5 $— $1.1 $194.6
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, 2017. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $0.9 $4.1 $1.3 $0.5 $1.0 Issuances of FTRs 8.9 31.0 9.6 5.0 7.1 Gains included as a regulatory liability/asset 9.0 7.5 6.7 3.1 4.3 Settlements (10.5 ) (14.3 ) (8.5 ) (3.4 ) (6.9 ) Balance as of June 30, $8.3 $28.3 $9.1 $5.2 $5.5 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 Entergy Entergy Entergy Entergy (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 six months ended June 30, 2017 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $5.4 $8.5 $3.2 $1.1 $3.1 Issuances of FTRs 8.9 31.0 9.6 5.0 7.1 Gains included as a regulatory liability/asset 9.1 18.3 7.9 4.8 7.4 Settlements (15.1 ) (29.5 ) (11.6 ) (5.7 ) (12.1 ) Balance as of June 30, $8.3 $28.3 $9.1 $5.2 $5.5 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
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, 2017 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $8.3 Entergy Arkansas Financial transmission rights Prepayments and other $28.3 Entergy Louisiana Financial transmission rights Prepayments and other $9.1 Entergy Mississippi Financial transmission rights Prepayments and other $5.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.5 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $4.5 Entergy Louisiana Natural gas swaps Other current liabilities $0.8 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2016 are as follows: Instrument Balance Sheet Location Fair Value (a) Registrant (In Millions) Assets: Natural gas swaps Prepayments and other $10.9 Entergy Louisiana Natural gas swaps Prepayments and other $2.3 Entergy Mississippi Natural gas swaps Prepayments and other $0.2 Entergy New Orleans Financial transmission rights Prepayments and other $5.4 Entergy Arkansas Financial transmission rights Prepayments and other $8.5 Entergy Louisiana Financial transmission rights Prepayments and other $3.2 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 Entergy New Orleans Financial transmission rights Prepayments and other $3.1 Entergy Texas (a) As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. As of December 31, 2016, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi.
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, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.6) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.4) (a) Entergy Mississippi FTRs Purchased power expense $10.5 (b) Entergy Arkansas FTRs Purchased power expense $14.3 (b) Entergy Louisiana FTRs Purchased power expense $8.5 (b) Entergy Mississippi FTRs Purchased power expense $3.4 (b) Entergy New Orleans FTRs Purchased power expense $6.9 (b) Entergy Texas 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 The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2017 and 2016 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($13.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $15.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $29.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $11.6 (b) Entergy Mississippi Financial transmission rights Purchased power expense $5.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $12.1 (b) Entergy Texas 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 Financial transmission rights Purchased power expense $13.3 (b) Entergy Arkansas Financial transmission rights Purchased power expense $32.1 (b) Entergy Louisiana Financial transmission rights Purchased power expense $4.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $1.9 (b) Entergy New Orleans Financial transmission rights Purchased power expense $6.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Assets and liabilities at fair value on a recurring basis	Entergy Texas 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets : Securitization recovery trust account $28.7 $— $— $28.7 Financial transmission rights — — 5.5 5.5 $28.7 $— $5.5 $34.2 2016 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $5.0 $— $— $5.0 Securitization recovery trust account 37.5 — — 37.5 Financial transmission rights — — 3.1 3.1 $42.5 $— $3.1 $45.6
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, 2017. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $0.9 $4.1 $1.3 $0.5 $1.0 Issuances of FTRs 8.9 31.0 9.6 5.0 7.1 Gains included as a regulatory liability/asset 9.0 7.5 6.7 3.1 4.3 Settlements (10.5 ) (14.3 ) (8.5 ) (3.4 ) (6.9 ) Balance as of June 30, $8.3 $28.3 $9.1 $5.2 $5.5 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 Entergy Entergy Entergy Entergy (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 six months ended June 30, 2017 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $5.4 $8.5 $3.2 $1.1 $3.1 Issuances of FTRs 8.9 31.0 9.6 5.0 7.1 Gains included as a regulatory liability/asset 9.1 18.3 7.9 4.8 7.4 Settlements (15.1 ) (29.5 ) (11.6 ) (5.7 ) (12.1 ) Balance as of June 30, $8.3 $28.3 $9.1 $5.2 $5.5 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
System Energy [Member]
Assets and liabilities at fair value on a recurring basis	System Energy 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $337.0 $— $— $337.0 Decommissioning trust funds (a): Equity securities 1.6 — — 1.6 Debt securities 208.9 113.6 — 322.5 Common trusts (b) 515.3 $547.5 $113.6 $— $1,176.4 2016 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $245.1 $— $— $245.1 Decommissioning trust funds (a): Equity securities 0.3 — — 0.3 Debt securities 248.3 58.3 — 306.6 Common trusts (b) 473.6 $493.7 $58.3 $— $1,025.6

Decommissioning Trust Funds (Ta

Decommissioning Trust Funds (Tables)	6 Months Ended
	Jun. 30, 2017
Securities Held	The securities held as of June 30, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $4,389 $1,857 $1 Debt Securities 2,408 45 15 Total $6,797 $1,902 $16 Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2016 Equity Securities $3,511 $1,673 $1 Debt Securities 2,213 34 27 Total $5,724 $1,707 $28
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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $2 $1 $997 $12 More than 12 months — — 47 3 Total $2 $1 $1,044 $15 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $23 $1 $1,169 $26 More than 12 months 1 — 20 1 Total $24 $1 $1,189 $27
Fair Value Of Debt Securities By Contractual Maturities	The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $106 $125 1 year - 5 years 805 763 5 years - 10 years 795 719 10 years - 15 years 111 109 15 years - 20 years 88 73 20 years+ 503 424 Total $2,408 $2,213
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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $556.3 $308.0 $— Debt Securities 328.0 3.3 2.3 Total $884.3 $311.3 $2.3 2016 Equity Securities $525.4 $281.5 $— Debt Securities 309.3 3.4 4.2 Total $834.7 $284.9 $4.2
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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $118.1 $1.7 More than 12 months — — 10.1 0.6 Total $— $— $128.2 $2.3 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $146.7 $4.2 More than 12 months — — — — Total $— $— $146.7 $4.2
Fair Value Of Debt Securities By Contractual Maturities	The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $16.8 $16.7 1 year - 5 years 102.6 106.2 5 years - 10 years 183.5 161.2 10 years - 15 years 4.4 7.7 15 years - 20 years 1.1 1.0 20 years+ 19.6 16.5 Total $328.0 $309.3
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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $756.6 $395.6 $— Debt Securities 464.1 10.9 2.9 Total $1,220.7 $406.5 $2.9 2016 Equity Securities $715.9 $346.6 $— Debt Securities 424.8 8.0 5.0 Total $1,140.7 $354.6 $5.0
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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $164.4 $2.4 More than 12 months — — 9.7 0.5 Total $— $— $174.1 $2.9 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $198.8 $4.8 More than 12 months — — 4.8 0.2 Total $— $— $203.6 $5.0
Fair Value Of Debt Securities By Contractual Maturities	The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $28.5 $31.4 1 year - 5 years 105.2 99.1 5 years - 10 years 131.9 122.8 10 years - 15 years 44.3 41.4 15 years - 20 years 38.6 30.9 20 years+ 115.6 99.2 Total $464.1 $424.8
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, 2017 and December 31, 2016 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2017 Equity Securities $516.9 $257.6 $— Debt Securities 322.5 3.3 2.3 Total $839.4 $260.9 $2.3 2016 Equity Securities $473.9 $221.9 $0.1 Debt Securities 306.6 2.0 4.5 Total $780.5 $223.9 $4.6
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, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $199.5 $2.0 More than 12 months — — 8.6 0.3 Total $— $— $208.1 $2.3 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, 2016 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $220.9 $4.4 More than 12 months — 0.1 0.8 0.1 Total $— $0.1 $221.7 $4.5
Fair Value Of Debt Securities By Contractual Maturities	The fair value of debt securities, summarized by contractual maturities, as of June 30, 2017 and December 31, 2016 are as follows: 2017 2016 (In Millions) less than 1 year $8.6 $6.6 1 year - 5 years 159.6 188.2 5 years - 10 years 86.4 78.5 10 years - 15 years 2.3 1.3 15 years - 20 years 7.8 7.8 20 years+ 57.8 24.2 Total $322.5 $306.6

Commitments and Contingencies C

Commitments and Contingencies Commitments And Contingencies (Narrative) (Details) (Details) - USD ($) $ in Millions	1 Months Ended
	Oct. 31, 2016	Sep. 30, 2016	Apr. 30, 2016
River Bend [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Litigation Settlement, Amount		$ 5	$ 42
Palisades [Member] | Entergy Wholesale Commodities [Member]
Regulatory Assets [Line Items]
Litigation Settlement, Amount		14
Damages awarded for previously capitalized costs		11
Damages awarded for previously recorded operation and maintenance		$ 3
Indian Point 2 [Member] | Entergy Wholesale Commodities [Member]
Regulatory Assets [Line Items]
Litigation Settlement, Amount	$ 34
Damages awarded for previously capitalized costs	14
Damages awarded for previously recorded operation and maintenance	15
Damages awarded for previously recorded decommissioning expense	3
Damages awarded for previously recorded taxes other than income taxes	$ 2

Rate And Regulatory Matters (Na

Rate And Regulatory Matters (Narrative) (Details)	1 Months Ended										6 Months Ended
	Jul. 31, 2017USD ($)	Jun. 30, 2017USD ($)	May 31, 2017USD ($)	Apr. 30, 2017USD ($)	Mar. 31, 2017$ / kWh	Jan. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Nov. 30, 2016USD ($)	Sep. 30, 2016USD ($)	Apr. 30, 2016	Jun. 30, 2017USD ($)	Jun. 30, 2016USD ($)	Mar. 31, 2016USD ($)
Regulatory Assets [Line Items]
Impairment of Long-Lived Assets Held-for-use											$ 220,828,000	$ 14,329,000
Payments to Acquire Property, Plant, and Equipment											0	(947,903,000)
Deferred Fuel Cost		$ 194,245,000					$ 108,465,000				194,245,000
Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Payments to Acquire Property, Plant, and Equipment											0	(473,956,000)
Deferred Fuel Cost		25,902,000					0				25,902,000
Refund To Customers						$ 71,000,000
Earned return on common equity			9.84%
Formula rate plan revenue decrease			$ 16,900,000
Formula rate plan revenue decrease resulting from legacy Entergy Louisiana revenue			3,500,000
Formula rate plan revenue decrease resulting from legacy Entergy Gulf States Louisiana revenue			9,700,000
Formula rate plan revenue decrease resulting from incremental revenue			3,600,000
Adjustment to formula rate plan for reduction in MISO cost recovery mechanism			40,500,000
Current MISO formula rate plan cost recovery											46,800,000
Reduced proposed MISO formula rate plan cost recovery			6,300,000
Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Deferred Fuel Cost		20,579,000					6,957,000				20,579,000
Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Payments to Acquire Property, Plant, and Equipment											0	(236,978,000)
Long-term payable due to Entergy Louisiana		18,423,000					18,423,000				18,423,000
Deferred Fuel Cost		2,731,000					4,818,000				2,731,000
Energy Smart Program Funding				$ 11,800,000
Proposed customer credits in current year			10,000,000
Proposed customer credits in first quarter of year after transaction closes			1,400,000
Proposed customer credits per month in second year after transaction closes			117,500
Proposed customer credits upon FERC approval			$ 5,000,000
Entergy Texas [Member]
Regulatory Assets [Line Items]
Unspecific disallowance associated with settlement agreement							6,000,000
Projected Over-Recovery Balance								$ 21,000,000
Refund for fuel cost recovery		30,700,000
Amount Collected From Customers							29,500,000		$ 29,500,000		10,500,000
Requested increase in retail revenues per request for annual distribution cost recovery factor rider		19,000,000
Book Value of Existing Meters to be Retired with AMI Deployment							41,000,000
Current annual collection from distribution cost recovery factor rider		8,650,000
Entergy Texas [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Amended annual revenue requirement from distribution cost recovery factor rider	$ 18,300,000
Estimated nominal benefit to Customers Anticipated with AMI Deployment	33,000,000
Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Payments to Acquire Property, Plant, and Equipment											0	$ (236,969,000)
Deferred Fuel Cost		$ 145,033,000					$ 96,690,000				$ 145,033,000
Rate At Which Electricity Sold To Retail Customers | $ / kWh					0.01164
Increase in Rate At Which Electricity Sold To Retail Customers | $ / kWh					0.01547
ALJ Recommended Percentage By Which Payments Be Reduced										20.00%
Liability Recorded Related to Estimated Payments Due Utility Operating Companies													$ 87,000,000
Regulatory Asset Recorded to Represent Estimate of Recoverable Retail Portion of Costs													$ 75,000,000
Entergy Arkansas [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Projected Increase in Revenue Requirement	$ 129,700,000
Earned return on common equity	9.75%
Annual revenue constraint per rate class percentage	400.00%
Reduced requested increase in revenue requirement to comply with annual revenue constraint	$ 70,900,000
Payments due Utility Operating Companies Related to Opportunity Sales Proceedings	$ 86,000,000
System Energy [Member]
Regulatory Assets [Line Items]
Earned return on common equity											10.94%
System Energy [Member] | Minimum [Member]
Regulatory Assets [Line Items]
Recommended adjustment to earned return on equity						8.37%
System Energy [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Recommended adjustment to earned return on equity						8.67%
Natural Gas Processing Plant [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Earned return on common equity						6.37%
Requested Recovery of Previously Deferred Operation and Maintenance Expenses						$ 1,500,000
Public Utilities, Requested Increase in Revenue Requirement				$ 1,200,000		$ 1,400,000

Equity (Narrative) (Details)

Equity (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	Jul. 28, 2017	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Equity [Abstract]
Stock Options Excluded From Diluted Common Shares Outstanding Calculation		2,500,000	4,100,000	3,700,000	5,100,000
Dividends, Common Stock, Cash				$ 312,209	$ 303,843
Shares, Issued		390,013		390,013
Common stock dividend (in dollars per share)		$ 0.87	$ 0.85	$ 1.74	$ 1.70
Entergy Louisiana [Member]
Equity [Abstract]
Dividends, Common Stock, Cash				$ 91,250	$ 105,500
Entergy Mississippi [Member]
Equity [Abstract]
Dividends, Common Stock, Cash					24,000
System Energy [Member]
Equity [Abstract]
Dividends, Common Stock, Cash					$ 139,000
Subsequent Event [Member]
Equity [Abstract]
Common stock dividend (in dollars per share)	$ 0.87

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, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Incremental Weighted Average Shares Attributable to Dilutive Effect [Abstract]
Stock options, Shares	0	200,000	0	0
Stock options $/share	$ 0	$ 0	$ 0	$ 0
Restricted stock, Shares	0	500,000	0	400,000
Restricted stock $/share	$ (0.01)	$ (0.01)	$ (0.01)	$ (0.01)
Basic earnings per share
Net income (loss) attributable to Entergy Corporation, Income	$ 409,922	$ 567,314	$ 492,528	$ 797,280
Net Income Attributable to Entergy Corporation, Shares	179,475,346	178,808,149	179,405,592	178,693,342
Net Income Attributable to Entergy Corporation, $/share	$ 2.28	$ 3.17	$ 2.75	$ 4.46
Diluted earnings per share, Shares	180,234,694	179,503,582	180,032,233	179,233,209
Diluted earnings per share $/share	$ 2.27	$ 3.16	$ 2.74	$ 4.45

Equity (Accumulated Other Compr

Equity (Accumulated Other Comprehensive Income (Loss))(Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	$ 10,960	$ 29,792	$ (34,971)	$ 8,951
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	61,179	(11,026)	133,659	104,029
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(19,366)	(27,921)	(45,915)	(122,135)
Other comprehensive income (loss)	41,813	(38,947)	87,744	(18,106)
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	52,773	(9,155)	52,773	(9,155)
Foreign Currency Translation [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	748	1,744	748	2,028
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(748)	(904)	(748)	(1,188)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	0	0	0	0
Other comprehensive income (loss)	(748)	(904)	(748)	(1,188)
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	0	840	0	840
Net Unrealized Investment Gains [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	467,561	390,626	429,734	367,557
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	33,870	24,016	73,742	49,048
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(22,174)	(3,061)	(24,219)	(5,024)
Other comprehensive income (loss)	11,696	20,955	49,523	44,024
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	479,257	411,581	479,257	411,581
Pension And Other Postretirement Liabilities [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	(460,814)	(459,042)	(469,446)	(466,604)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0	0	0	0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	10,916	5,043	19,548	12,605
Other comprehensive income (loss)	10,916	5,043	19,548	12,605
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	(449,898)	(453,999)	(449,898)	(453,999)
Cash Flow Hedges Net Unrealized Gain [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	3,465	96,464	3,993	105,970
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	28,057	(34,138)	60,665	56,169
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(8,108)	(29,903)	(41,244)	(129,716)
Other comprehensive income (loss)	19,949	(64,041)	19,421	(73,547)
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	23,414	32,423	23,414	32,423
Entergy Louisiana [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance			(48,442)
Other comprehensive income (loss)	(310)	(230)	(680)	(493)
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	(49,122)		(49,122)
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	(48,812)	(56,675)	(48,442)	(56,412)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(310)	(230)	(680)	(493)
Other comprehensive income (loss)	(310)	(230)	(680)	(493)
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	$ (49,122)	$ (56,905)	$ (49,122)	$ (56,905)

Equity (Reclassification out of

Equity (Reclassification out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017		Jun. 30, 2016
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Competitive Energy Revenue	$ 317,255	$ 344,110	$ 870,622		$ 866,189
Other Nonoperating Income (Expense)	(6,872)	(8,377)	(1,371)		(18,963)
INCOME BEFORE INCOME TAXES	76,256	323,617	170,070		698,805
Income taxes (benefits)	337,112	248,973	329,350		109,027
Consolidated net income	413,368	572,590	499,420	[1]	807,832	[1]
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Consolidated net income	19,366	27,921	45,915		122,135
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	22,174	3,061	24,219		5,024
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	12,695	45,975	63,922		199,933
Other Nonoperating Income (Expense)	(219)	30	(469)		(370)
INCOME BEFORE INCOME TAXES	12,476	46,005	63,453		199,563
Income taxes (benefits)	(4,368)	(16,102)	(22,209)		(69,847)
Consolidated net income	8,108	29,903	41,244		129,716
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)	43,479	6,000	47,489		9,850
Income taxes (benefits)	(21,305)	(2,939)	(23,270)		(4,826)
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	6,564	7,355	13,126		14,710
Amortization of loss	(21,554)	(15,177)	(43,125)		(30,352)
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Settlements	(1,765)	0	(1,765)		0
INCOME BEFORE INCOME TAXES	(16,755)	(7,822)	(31,764)		(15,642)
Income taxes (benefits)	5,839	2,779	12,216		3,037
Consolidated net income	(10,916)	(5,043)	(19,548)		(12,605)
Entergy Louisiana [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Nonoperating Income (Expense)	(2,650)	(1,870)	(5,674)		(5,615)
INCOME BEFORE INCOME TAXES	181,215	168,235	318,518		329,583
Income taxes (benefits)	(56,736)	85,090	(99,661)		35,348
Consolidated net income	124,479	253,325	218,857		364,931
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	1,934	1,947	3,868		3,894
Amortization of loss	(1,332)	(1,573)	(2,664)		(3,142)
INCOME BEFORE INCOME TAXES	602	374	1,204		752
Income taxes (benefits)	(292)	(144)	(524)		(259)
Consolidated net income	$ 310	$ 230	$ 680		$ 493
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2017 and 2016 include $6.9 million and $10.6 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Revolving Credit Facilities, 37

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended				6 Months Ended
	Oct. 31, 2017	Jul. 31, 2017	May 31, 2017	Feb. 28, 2017	Jun. 30, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Amount of Facility					$ 3,500,000
Issuance of letters of credit, percentage of total borrowing capacity					50.00%
Letters of Credit Outstanding, Amount					$ 19,000
Line of credit facility, commitment fee percentage					0.225%
Amount Drawn/ Outstanding					$ 225,000
Commercial Paper program limit					1,500,000
Commercial Paper Amount Outstanding					$ 1,100,000
Commercial Paper Program [Member]
Debt Instrument [Line Items]
Debt, weighted average interest rate					1.38%
Credit Facility [Member]
Debt Instrument [Line Items]
Debt, weighted average interest rate					2.38%
Entergy Arkansas [Member]
Debt Instrument [Line Items]
Short-term borrowings					$ 14,696	$ 0
Authorized Short Term Borrowings					$ 250,000
Issuance of letters of credit, percentage of total borrowing capacity					50.00%
Letters of Credit Outstanding, Amount					$ 300	300
Entergy Arkansas [Member] | Three Point Five Percent Series First Mortgage Bonds Due April Two Thousand Twenty Six [Member]
Debt Instrument [Line Items]
Issuance Of Debt			$ 220,000
Debt instrument, interest rate, stated percentage			3.50%
Entergy Louisiana [Member]
Debt Instrument [Line Items]
Short-term borrowings					34,490	3,794
Authorized Short Term Borrowings					$ 450,000
Issuance of letters of credit, percentage of total borrowing capacity					50.00%
Redemption of debt instrument			$ 45,300
Entergy Louisiana [Member] | 3.12% collateral trust mortgage bonds due September 2027 [Domain]
Debt Instrument [Line Items]
Issuance Of Debt			$ 450,000
Debt instrument, interest rate, stated percentage			3.12%
Entergy Mississippi [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings					$ 175,000
Letters of Credit Outstanding, Amount					100	100
Entergy Texas [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings					$ 200,000
Issuance of letters of credit, percentage of total borrowing capacity					50.00%
System Energy [Member]
Debt Instrument [Line Items]
Short-term borrowings					$ 53,182	$ 66,893
Authorized Short Term Borrowings					200,000
Entergy Nuclear Vermont Yankee [Member]
Debt Instrument [Line Items]
Amount of Facility					$ 100,000
Line of credit facility, commitment fee percentage					0.20%
Amount Drawn/ Outstanding					$ 71,000
Line of Credit Facility, Interest Rate During Period					2.44%
Uncommitted Credit Facility					$ 85,000
Uncommitted Line of Credit Facility Interest Rate During Period					2.72%
Entergy New Orleans [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings					$ 100,000
Issuance of letters of credit, limit of total borrowing capacity					10,000
System Energy VIE [Member]
Debt Instrument [Line Items]
Short-term borrowings					53,200
Amount Drawn/ Outstanding					$ 103,200
Line of credit facility commitment fee as a percentage of undrawn commitment amount					0.10%
System Energy VIE [Member] | Three Point Seven Eight Percent Series I Notes Due October Two Thousand Eighteen [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					3.78%
System Energy VIE [Member] | Four Point Zero Two Percent Series H Notes [Domain]
Debt Instrument [Line Items]
Redemption of debt instrument				$ 50,000
Debt instrument, interest rate, stated percentage				4.02%
Entergy Arkansas VIE [Member]
Debt Instrument [Line Items]
Short-term borrowings					$ 14,700
Amount Drawn/ Outstanding					$ 31,400
Line of credit facility commitment fee as a percentage of undrawn commitment amount					0.10%
Entergy Arkansas VIE [Member] | Three Point Six Five Percent Series L Notes Due July Two Thousand Twenty One [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					3.65%
Entergy Louisiana Waterford VIE [Member]
Debt Instrument [Line Items]
Short-term borrowings					$ 34,500
Amount Drawn/ Outstanding					$ 70,800
Line of credit facility commitment fee as a percentage of undrawn commitment amount					0.10%
Entergy Louisiana Waterford VIE [Member] | Three Point Nine Two Percent Series H Dues February Two Thousand Twenty One [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					3.92%
Entergy Louisiana River Bend VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding					$ 15,500
Line of credit facility commitment fee as a percentage of undrawn commitment amount					0.10%
Maximum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment fee percentage					0.275%
Consolidated debt ratio					65.00%
Maximum [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Consolidated debt ratio					65.00%
Consolidated debt ratio of total capitalization					70.00%
Maximum [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Consolidated debt ratio					65.00%
Consolidated debt ratio of total capitalization					70.00%
Maximum [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Consolidated debt ratio					65.00%
Maximum [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Consolidated debt ratio					65.00%
Maximum [Member] | System Energy [Member]
Debt Instrument [Line Items]
Consolidated debt ratio of total capitalization					70.00%
Maximum [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Consolidated debt ratio					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					$ 150,000
Letters of Credit Outstanding, Amount					0
Amount Drawn/ Outstanding					$ 0
Line of Credit Facility, Interest Rate During Period					2.48%
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Amount of Facility					$ 150,000
Letters of Credit Outstanding, Amount					13,300
Amount Drawn/ Outstanding					$ 0
Line of Credit Facility, Interest Rate During Period					2.73%
Subsequent Event [Member] | Entergy Arkansas [Member] | 1.55% Pollution Control Revenue Refunding Bonds [Domain]
Debt Instrument [Line Items]
Redemption of debt instrument	$ 54,700
Debt instrument, interest rate, stated percentage	1.55%
Subsequent Event [Member] | Entergy Louisiana Waterford VIE [Member] | 3.25% Series G notes [Domain]
Debt Instrument [Line Items]
Redemption of debt instrument		$ 25,000
Debt instrument, interest rate, stated percentage		3.25%
Subsequent Event [Member] | Entergy Louisiana River Bend VIE [Member] | 3.25% Series Q notes [Domain]
Debt Instrument [Line Items]
Redemption of debt instrument		$ 75,000
Debt instrument, interest rate, stated percentage		3.25%

Revolving Credit Facilities, 38

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Summary Of The Borrowings Outstanding And Capacity Available Under The Facility) (Details) $ in Millions	Jun. 30, 2017USD ($)
Summary of the borrowings outstanding and capacity available under the facility
Capacity	$ 3,500
Amount Drawn/ Outstanding	225
Letters of Credit	6
Capacity Available	$ 3,269

Revolving Credit Facilities, 39

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Credit Facilities) (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2017	Dec. 31, 2016
Amount of Facility	$ 3,500,000
Amount Drawn/ Outstanding	225,000
Letters of Credit Outstanding, Amount	19,000
Entergy Arkansas [Member]
Letters of Credit Outstanding, Amount	$ 300	$ 300
Entergy Arkansas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Aug. 14, 2021
Amount of Facility	$ 150,000
Interest Rate	2.48%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Arkansas [Member] | Credit Facility Of Twenty Million [Member]
Expiration Date	Apr. 30, 2018
Amount of Facility	$ 20,000
Interest Rate	2.48%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Louisiana [Member] | Credit Facility Of Three Hundred Fifty Million [Member]
Expiration Date	Aug. 14, 2021
Amount of Facility	$ 350,000
Interest Rate	2.48%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	4,500
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	$ 100	$ 100
Entergy Mississippi [Member] | Credit Facility Of Thirty Seven Point Five Million [Member]
Expiration Date	May 31, 2018
Amount of Facility	$ 37,500
Interest Rate	2.73%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Thirty Five Million [Member]
Expiration Date	May 31, 2018
Amount of Facility	$ 35,000
Interest Rate	2.73%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Twenty Million [Member]
Expiration Date	May 31, 2018
Amount of Facility	$ 20,000
Interest Rate	2.73%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Ten Million [Member]
Expiration Date	May 31, 2018
Amount of Facility	$ 10,000
Interest Rate	2.73%
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	2.70%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 800
Entergy Texas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Aug. 14, 2021
Amount of Facility	$ 150,000
Interest Rate	2.73%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 13,300

Revolving Credit Facilities, 40

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Short-Term Borrowings And The Outstanding Short-Term Borrowings) (Details) $ in Millions	Jun. 30, 2017USD ($)
Entergy Arkansas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	$ 250
Borrowings	14
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	56
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	39
System Energy [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	$ 0

Revolving Credit Facilities, 41

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2017USD ($)
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount Drawn/ Outstanding	$ 225
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	2.39%
Amount Drawn/ Outstanding	$ 31.4
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
System Energy VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	May 16, 2019
Amount of Facility	$ 120
Weighted Average Interest Rate on Borrowings	2.42%
Amount Drawn/ Outstanding	$ 103.2
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
Entergy Louisiana River Bend VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	May 16, 2019
Amount of Facility	$ 105
Weighted Average Interest Rate on Borrowings	2.12%
Amount Drawn/ Outstanding	$ 15.5
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
Entergy Louisiana Waterford VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	May 16, 2019
Amount of Facility	$ 85
Weighted Average Interest Rate on Borrowings	2.38%
Amount Drawn/ Outstanding	$ 70.8
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%

Revolving Credit Facilities, 42

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Notes Payable By Variable Interest Entities) (Details) $ in Millions	Jun. 30, 2017USD ($)
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 One Seven Percent Series M Notes Due December Two Thousand Twenty Three [Member] | Entergy Arkansas VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.17%
Amount	$ 40
Three Point 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
Three Point Two Two Percent Series I Notes Due December Two Thousand Twenty Three [Domain] | Entergy Louisiana Waterford VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.22%
Amount	$ 20
Three Point Seven Eight Percent Series I Notes Due October Two Thousand Eighteen [Member] | System Energy VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.78%
Amount	$ 85

Revolving Credit Facilities, 43

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Book Value And The Fair Value Of Long-Term Debt) (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Long-term Debt, Fair Value	$ 15,239,655	$ 14,815,535
Long-term Debt, Book Value	15,010,668	14,832,555
Entergy Arkansas [Member]
Long-term Debt, Fair Value	2,942,288	2,623,910
Long-term Debt, Book Value	3,064,261	2,829,785
Long term DOE obligations	182,000	182,000
Entergy Louisiana [Member]
Long-term Debt, Fair Value	6,484,470	5,929,488
Long-term Debt, Book Value	6,246,015	5,812,791
Capital Lease Obligations		57,000
Entergy Mississippi [Member]
Long-term Debt, Fair Value	1,137,274	1,086,203
Long-term Debt, Book Value	1,121,356	1,120,916
Entergy New Orleans [Member]
Long-term Debt, Fair Value	467,094	455,459
Long-term Debt, Book Value	444,159	448,994
Entergy Texas [Member]
Long-term Debt, Fair Value	1,560,208	1,600,156
Long-term Debt, Book Value	1,471,091	1,508,407
System Energy [Member]
Long-term Debt, Fair Value	482,650	529,520
Long-term Debt, Book Value	551,296	551,132
Capital Lease Obligations	$ 34,000	$ 34,000

Revolving Credit Facilities, 44

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations) (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Letters of Credit Outstanding, Amount	$ 19
Entergy Arkansas [Member]
Letters of Credit Outstanding, Amount	0.3	$ 0.3
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	0.1	$ 0.1
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	$ 22.3
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	$ 7.8
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	$ 5.6
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	$ 36.8

Stock Based Compensation (Narra

Stock Based Compensation (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	Jan. 26, 2017	Jan. 31, 2017	Mar. 31, 2017	Jun. 30, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option granted (in shares)			791,900
Weighted-average grant-date fair value of options granted (in dollars per share)			$ 6.54
Stock options outstanding				6,162,359
Weighted-average exercise price of stock options outstanding (in dollars per share)				$ 81.65
Intrinsic value in the money stock options				$ 21.5
Vesting period of awards under Entergy's plans, years				3 years
Equity Ownership And Long Term Cash Incentive Plan Two Thousand Fifteen [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
LTIP awards granted value (in dollars per share)	$ 71.40
Restricted Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock awards granted value (in dollars per share)	$ 70.53
Restricted Awards [Member] | Equity Ownership And Long Term Cash Incentive Plan Two Thousand Fifteen [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock awards granted		379,850
Long-term incentive plan awards		220,450

Stock-Based Compensation (Finan

Stock-Based Compensation (Financial Information For Stock Options) (Details) - Employee Stock Option [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 1.1	$ 1.1	$ 2.2	$ 2.2
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 (Fin47

Stock-Based Compensation (Financial Information For Other Equity Plans) (Details) - Restricted Stock Awards [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 8.2	$ 8.5	$ 16.4	$ 16.9
Tax benefit recognized in Entergy's net income	3.2	3.3	6.3	6.5
Compensation cost capitalized as part of fixed assets and inventory	$ 2.2	$ 1.9	$ 4.2	$ 3.7

Retirement And Other Postreti48

Retirement And Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2017
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Contributions by Employer			$ 176,000
Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Contributions by Employer			34,507
Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plans, Estimated Future Employer Contributions in Current Fiscal Year					$ 409,900
Subsequent Event [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plans, Estimated Future Employer Contributions in Current Fiscal Year					79,495
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year					$ 44,988
Non-Qualified Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	$ 8,500	$ 4,300	13,100	$ 8,500
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits	4,000		4,000
Non-Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	$ 267	$ 106	372	$ 212
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits			$ 163

Retirement And Other Postreti49

Retirement And Other Postretirement Benefits (Components Of Qualified Net Pension Cost) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	$ 33,410	$ 35,811	$ 66,820	$ 71,622
Interest cost on projected benefit obligation	65,206	65,403	130,412	130,806
Expected return on assets	(102,056)	(97,366)	(204,112)	(194,732)
Amortization of prior service cost (credit)	65	270	130	540
Amortization of loss	56,930	48,824	113,860	97,648
Net other postretirement benefit cost	53,555	52,942	107,110	105,884
Pension Plans Defined Benefit [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	5,090	5,181	10,180	10,362
Interest cost on projected benefit obligation	12,944	13,055	25,888	26,110
Expected return on assets	(20,427)	(19,772)	(40,854)	(39,544)
Amortization of loss	11,640	10,936	23,280	21,872
Net other postretirement benefit cost	9,247	9,400	18,494	18,800
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	6,925	7,049	13,850	14,098
Interest cost on projected benefit obligation	14,809	14,870	29,618	29,740
Expected return on assets	(23,017)	(22,096)	(46,034)	(44,192)
Amortization of loss	12,354	11,946	24,708	23,892
Net other postretirement benefit cost	11,071	11,769	22,142	23,538
Pension Plans Defined Benefit [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,472	1,562	2,944	3,124
Interest cost on projected benefit obligation	3,732	3,811	7,464	7,622
Expected return on assets	(6,131)	(5,981)	(12,262)	(11,962)
Amortization of loss	3,053	2,985	6,106	5,970
Net other postretirement benefit cost	2,126	2,377	4,252	4,754
Pension Plans Defined Benefit [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	625	656	1,250	1,312
Interest cost on projected benefit obligation	1,791	1,814	3,582	3,628
Expected return on assets	(2,800)	(2,687)	(5,600)	(5,374)
Amortization of loss	1,658	1,615	3,316	3,230
Net other postretirement benefit cost	1,274	1,398	2,548	2,796
Pension Plans Defined Benefit [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,364	1,416	2,728	2,832
Interest cost on projected benefit obligation	3,392	3,557	6,784	7,114
Expected return on assets	(6,180)	(6,062)	(12,360)	(12,124)
Amortization of loss	2,310	2,340	4,620	4,680
Net other postretirement benefit cost	886	1,251	1,772	2,502
Pension Plans Defined Benefit [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,536	1,566	3,072	3,132
Interest cost on projected benefit obligation	3,091	2,992	6,182	5,984
Expected return on assets	(4,663)	(4,459)	(9,326)	(8,918)
Amortization of loss	2,964	2,604	5,928	5,208
Net other postretirement benefit cost	2,928	2,703	5,856	5,406
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	6,729	8,073	13,458	16,146
Interest cost on projected benefit obligation	13,960	14,083	27,920	28,166
Expected return on assets	(9,408)	(10,455)	(18,816)	(20,910)
Amortization of prior service cost (credit)	(10,356)	(11,373)	(20,712)	(22,746)
Amortization of loss	5,476	4,554	10,952	9,108
Net other postretirement benefit cost	6,401	4,882	12,802	9,764
Other Postretirement [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	863	978	1,726	1,956
Interest cost on projected benefit obligation	2,255	2,324	4,510	4,648
Expected return on assets	(3,959)	(4,464)	(7,918)	(8,928)
Amortization of prior service cost (credit)	(1,278)	(1,368)	(2,556)	(2,736)
Amortization of loss	1,115	1,064	2,230	2,128
Net other postretirement benefit cost	(1,004)	(1,466)	(2,008)	(2,932)
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,593	1,869	3,186	3,738
Interest cost on projected benefit obligation	3,025	3,260	6,050	6,520
Expected return on assets	0	0	0	0
Amortization of prior service cost (credit)	(1,934)	(1,947)	(3,868)	(3,894)
Amortization of loss	465	732	930	1,464
Net other postretirement benefit cost	3,149	3,914	6,298	7,828
Other Postretirement [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	290	386	580	772
Interest cost on projected benefit obligation	690	709	1,380	1,418
Expected return on assets	(1,200)	(1,379)	(2,400)	(2,758)
Amortization of prior service cost (credit)	(456)	(234)	(912)	(468)
Amortization of loss	419	223	838	446
Net other postretirement benefit cost	(257)	(295)	(514)	(590)
Other Postretirement [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	142	156	284	312
Interest cost on projected benefit obligation	469	448	938	896
Expected return on assets	(1,159)	(1,154)	(2,318)	(2,308)
Amortization of prior service cost (credit)	(186)	(186)	(372)	(372)
Amortization of loss	105	37	210	74
Net other postretirement benefit cost	(629)	(699)	(1,258)	(1,398)
Other Postretirement [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	372	398	744	796
Interest cost on projected benefit obligation	1,124	1,039	2,248	2,078
Expected return on assets	(2,180)	(2,394)	(4,360)	(4,788)
Amortization of prior service cost (credit)	(579)	(681)	(1,158)	(1,362)
Amortization of loss	826	537	1,652	1,074
Net other postretirement benefit cost	(437)	(1,101)	(874)	(2,202)
Other Postretirement [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	320	334	640	668
Interest cost on projected benefit obligation	559	529	1,118	1,058
Expected return on assets	(717)	(814)	(1,434)	(1,628)
Amortization of prior service cost (credit)	(378)	(393)	(756)	(786)
Amortization of loss	390	287	780	574
Net other postretirement benefit cost	174	(57)	348	(114)
Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	8,500	4,300	13,100	8,500
Non-Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	267	106	372	212
Non-Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	47	59	96	118
Non-Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	63	59	127	118
Non-Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	18	16	36	32
Non-Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	$ 126	$ 127	$ 253	$ 254

Retirement And Other Postreti50

Retirement And Other Postretirement Benefits (Expected Employer Contributions) (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2017	Dec. 31, 2017
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Contributions by Employer	$ 176,000
Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plans, Estimated Future Employer Contributions in Current Fiscal Year		$ 409,900
Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Contributions by Employer	37,519
Entergy Louisiana [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plans, Estimated Future Employer Contributions in Current Fiscal Year		87,923
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		50,404
Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Contributions by Employer	8,251
Entergy Mississippi [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plans, Estimated Future Employer Contributions in Current Fiscal Year		19,146
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		10,895
Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Contributions by Employer	4,361
Entergy New Orleans [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plans, Estimated Future Employer Contributions in Current Fiscal Year		9,920
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		5,559
Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Contributions by Employer	7,227
Entergy Texas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plans, Estimated Future Employer Contributions in Current Fiscal Year		17,064
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		9,837
System Energy [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Contributions by Employer	8,182
System Energy [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plans, Estimated Future Employer Contributions in Current Fiscal Year		18,180
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		9,998
Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Contributions by Employer	$ 34,507
Entergy Arkansas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plans, Estimated Future Employer Contributions in Current Fiscal Year		79,495
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		$ 44,988

Retirement And Other Postreti51

Retirement And Other Postretirement Benefits (Reclassification Out Of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	$ 6,564	$ 7,355	$ 13,126	$ 14,710
Amortization of loss	(21,554)	(15,177)	(43,125)	(30,352)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(1,765)		(1,765)
Total	(16,755)	(7,822)	(31,764)	(15,642)
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,934	1,947	3,868	3,894
Amortization of loss	(1,332)	(1,573)	(2,664)	(3,142)
Total	602	374	1,204	752
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(65)	(270)	(130)	(540)
Amortization of loss	(18,450)	(12,482)	(36,899)	(24,964)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0		0
Total	(18,515)	(12,752)	(37,029)	(25,504)
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	(865)	(836)	(1,730)	(1,672)
Total	(865)	(836)	(1,730)	(1,672)
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	6,718	7,738	13,435	15,476
Amortization of loss	(2,202)	(2,063)	(4,404)	(4,126)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0		0
Total	4,516	5,675	9,031	11,350
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,934	1,947	3,868	3,894
Amortization of loss	(465)	(732)	(930)	(1,464)
Total	1,469	1,215	2,938	2,430
Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(89)	(113)	(179)	(226)
Amortization of loss	(902)	(632)	(1,822)	(1,262)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(1,765)		(1,765)
Total	(2,756)	(745)	(3,766)	(1,488)
Non-Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0	0	0
Amortization of loss	(2)	(5)	(4)	(6)
Total	$ (2)	$ (5)	$ (4)	$ (6)

Business Segment Information Bu

Business Segment Information Business Segment Information (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Segment Reporting Information [Line Items]
Asset Write-Offs, Impairments, And Related Charges	$ 193,571	$ 6,969	$ 405,362	$ 14,329

Business Segment Information (S

Business Segment Information (Segment Financial Information) (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017		Jun. 30, 2016		Dec. 31, 2016
Segment Financial Information
Operating revenues	$ 2,618,550,000	$ 2,462,562,000	$ 5,207,008,000		$ 5,072,415,000
Income taxes (benefits)	(337,112,000)	(248,973,000)	(329,350,000)		(109,027,000)
Consolidated net income	413,368,000	572,590,000	499,420,000	[1]	807,832,000	[1]
Assets	46,007,037,000		46,007,037,000				$ 45,904,434,000
Utility [Member]
Segment Financial Information
Operating revenues	2,301,332,000	2,118,478,000	4,336,444,000		4,206,272,000
Income taxes (benefits)	130,851,000	(3,785,000)	229,343,000		104,051,000
Consolidated net income	246,382,000	380,317,000	414,005,000		579,968,000
Assets	42,263,832,000		42,263,832,000				41,098,751,000
Entergy Wholesale Commodities [Member]
Segment Financial Information
Operating revenues	317,255,000	344,110,000	870,622,000		866,189,000
Income taxes (benefits)	(454,944,000)	(235,055,000)	(533,281,000)		(182,741,000)
Consolidated net income	223,886,000	250,874,000	196,689,000		330,430,000
Assets	5,627,284,000		5,627,284,000				6,696,038,000
All Other [Member]
Segment Financial Information
Operating revenues	0	0	0		0
Income taxes (benefits)	(13,019,000)	(10,133,000)	(25,412,000)		(30,337,000)
Consolidated net income	(25,001,000)	(26,703,000)	(47,477,000)		(38,769,000)
Assets	1,165,157,000		1,165,157,000				1,283,816,000
Eliminations [Member]
Segment Financial Information
Operating revenues	(37,000)	(26,000)	(58,000)		(46,000)
Income taxes (benefits)	0	0	0		0
Consolidated net income	(31,899,000)	$ (31,898,000)	(63,797,000)		$ (63,797,000)
Assets	$ (3,049,236,000)		$ (3,049,236,000)				$ (3,174,171,000)
[1]	(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2017 and 2016 include $6.9 million and $10.6 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.

Business Segment Information 54

Business Segment Information Business Segment Information (Restructuring Costs) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Restructuring Charges	$ 42	$ 66
Payments for Restructuring	100	100
Restructuring Reserve	57	57	$ 115	$ 91
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	42	66
Payments for Restructuring	100	100
Restructuring Reserve	36	36	94	70
Economic Development Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	0	0
Payments for Restructuring	0	0
Restructuring Reserve	$ 21	$ 21	$ 21	$ 21

Risk Management and Fair Valu55

Risk Management and Fair Values (Narrative) (Details) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2017USD ($)GWhMMBTU	Jun. 30, 2016USD ($)	Jun. 30, 2017USD ($)GWhMMBTUTWh	Jun. 30, 2016USD ($)	Dec. 31, 2016USD ($)counterparty
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount	$ 19		$ 19
Cash collateral posted	1		1		$ 2
Derivative, Collateral, Obligation to Return Cash	3		3
Letters of Credit Held	19		19
Cash flow hedges relating to power sales as part of net unrealized gains			39
Reclassified from accumulated other comprehensive income (OCI) to operating revenues			30
Number of Derivative Contract Counterparties in a Liability Position | counterparty					3
Maturity of cash flow hedges, Tax	$ 4	$ 16	$ 22	$ 70
Maximum length of time over which Company is currently hedging the variability in future cash flows for forecasted power transactions, years			2 years 6 months
Planned generation sold forward from non utility nuclear power plants for the remainder of the period			89.00%
Planned Generation Sold Forward under financial derivatives	59.00%		59.00%
Total planned generation for remainder of the period | TWh			15,000,000
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	34,696,750		34,696,750
Total volume of fixed transmission rights outstanding | GWh	106,060		106,060
Change in cash flow hedges due to ineffectiveness	$ 5	(3)	$ 4	0
Dollar amount of hedge contract in a liability position					$ 8
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset and Liability Unrealized Gains (Loss) Included in Earnings	(0.1)	(6)	0.3
Entergy Arkansas [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount	$ 0.3		$ 0.3		0.3
Total volume of fixed transmission rights outstanding | GWh	24,188		24,188
Entergy Louisiana [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	29,110,800		29,110,800
Total volume of fixed transmission rights outstanding | GWh	47,173		47,173
Entergy Mississippi [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount	$ 0.1		$ 0.1		$ 0.1
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	5,585,950		5,585,950
Total volume of fixed transmission rights outstanding | GWh	14,075		14,075
Entergy New Orleans [Member]
Risk Management and Fair Values [Abstract]
Total volume of fixed transmission rights outstanding | GWh	5,316		5,316
Entergy Texas [Member]
Risk Management and Fair Values [Abstract]
Total volume of fixed transmission rights outstanding | GWh	14,572		14,572
Electricity Swaps And Options [Member]
Fair Value, Measurement With Unobservable Inputs Reconciliation, Recurring Basis, Asset and Liability, Realized Gain (Loss) Included In Earnings	$ 4	(9)	$ 4	(9)
Fixed Transmission Rights (FTRs) [Member]
Fair Value, Measurement With Unobservable Inputs Reconciliation, Recurring Basis, Asset and Liability, Realized Gain (Loss) Included In Earnings	$ 0	$ 0	$ 0	$ 0

Risk Management and Fair Valu56

Risk Management and Fair Values (Fair Values Of Derivative Instruments) (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Assets:
Derivative asset as hedging instrument offset	$ (3)
Other Non-Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Liabilities:
Derivative liability as hedging instrument offset	(10)	$ (7)
Derivative Liability, Fair Value, Gross Liability	12	16
Derivative Liability	2	9
Other Non-Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative liability as hedging instrument offset	(1)	(4)
Derivative Liability, Fair Value, Gross Liability	1	4
Derivative Liability	0	0
Other Deferred Debits And Other Assets [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset	19	6
Derivative asset as hedging instrument offset	(9)	(6)
Derivative Asset	10	0
Other Deferred Debits And Other Assets [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset	2	5
Derivative asset as hedging instrument offset	(2)	(5)
Derivative Asset	0	0
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	40	25
Derivative asset as hedging instrument offset	(23)	(14)
Derivative Asset	17	11
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	16	18
Derivative asset as hedging instrument offset	(3)	(13)
Derivative Asset	13	5
Prepayments And Other [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset, Fair Value, Gross Asset		13
Derivative asset as hedging instrument offset		0
Derivative Asset		13
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	61	22
Derivative asset as hedging instrument offset	(4)	(1)
Derivative Asset	57	21
Other Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Liabilities:
Derivative liability as hedging instrument offset	(15)	(10)
Derivative Liability, Fair Value, Gross Liability	15	11
Derivative Liability	0	1
Other Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative liability as hedging instrument offset	(10)	(17)
Derivative Liability, Fair Value, Gross Liability	10	18
Derivative Liability	0	1
Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative liability as hedging instrument offset	0
Derivative Liability, Fair Value, Gross Liability	5
Derivative Liability	5
Entergy Louisiana [Member] | Prepayments And Other [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset		10.9
Entergy Louisiana [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	28.3	8.5
Entergy Louisiana [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability	4.5
Entergy Mississippi [Member] | Prepayments And Other [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset		2.3
Entergy Mississippi [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	9.1	3.2
Entergy Mississippi [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability	0.8
Entergy New Orleans [Member] | Prepayments And Other [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset		0.2
Entergy New Orleans [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	5.2	1.1
Entergy Arkansas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	8.3	5.4
Entergy Texas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	$ 5.5	$ 3.1

Risk Management and Fair Valu57

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, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Effect of Derivative instruments designated as cash flow hedges on consolidated statements of income
Amount of gain (loss) recognized in AOCI (effective portion)	$ 43	$ (53)	$ 93	$ 86
Amount of gain reclassified from accumulated OCI into income (effective portion)	$ 13	$ 46	$ 64	$ 200

Risk Management and Fair Valu58

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, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
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	$ (5)	$ (10)	$ 4	$ 15
Amount of gain (loss) recorded in income	0	(6)	0	(9)
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	(9)	(6)	(16)	(30)
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	44	38	75	59
Entergy Arkansas [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	10.5	5.5	15.1	13.3
Entergy Louisiana [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	(7.6)	(4.9)	(13.7)	(24.2)
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	14.3	21.6	29.5	32.1
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	(1.4)	(0.9)	(2.5)	(5)
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	8.5	3.6	11.6	4.4
Entergy New Orleans [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income			(0.1)	(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	3.4	1.4	5.7	1.9
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	$ 6.9	$ 5.4	$ 12.1	$ 6.9

Risk Management and Fair Valu59

Risk Management and Fair Values (Assets And Liabilities At Fair Value On A Recurring Basis) (Details) - USD ($) $ in Millions		Jun. 30, 2017	Dec. 31, 2016
Assets at fair value on a recurring basis
Assets other than temporary cash investments		$ 6,797	$ 5,724
Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		867	1,058
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		7
Assets, Fair Value Disclosure		8,213	7,311
Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		5
Power Contracts Liabilities [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		2	11
Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		469	480
Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		2,408	2,213
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		3,920	3,031
Power Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		40	16
Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		416	433
Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		36	46
Gas Hedge Contracts Assets [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments			13
Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		57	21
Fair Value Inputs Level 1 [Member]
Assets at fair value on a recurring basis
Temporary cash investments		867	1,058
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		5
Assets, Fair Value Disclosure		2,820	3,015
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		5
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		469	480
Fair Value Inputs Level 1 [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		1,032	985
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		416	433
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		36	46
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			13
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
Liabilities, Fair Value Disclosure on Recurring Basis		0
Assets, Fair Value Disclosure		1,376	1,228
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		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		1,376	1,228
Fair Value, Inputs, Level 2 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 2 [Member] | Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 2 [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 2 [Member] | 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] | 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
Liabilities, Fair Value Disclosure on Recurring Basis		2
Assets, Fair Value Disclosure		97	37
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		2	11
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		40	16
Fair Value, Inputs, Level 3 [Member] | Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 3 [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 3 [Member] | 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] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		57	21
Entergy Mississippi [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments			76.8
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		41	114.1
Entergy Mississippi [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0.8
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		31.9	31.8
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			2.3
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		9.1	3.2
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			76.8
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		31.9	110.9
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0.8
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		31.9	31.8
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			2.3
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
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
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		9.1	3.2
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		9.1	3.2
Entergy Louisiana [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		1,220.7	1,140.7
Entergy Louisiana [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		211.9	163.9
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,756.6	1,632.5
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		4.5
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	[1]	11.2	13.9
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	[1]	464.1	424.8
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]	745.4	702
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		292.9	305.7
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		2.8	2.8
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			10.9
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		28.3	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		211.9	163.9
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		656.3	629.5
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		4.5
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	[1]	11.2	13.9
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	[1]	137.5	132.3
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		292.9	305.7
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		2.8	2.8
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			10.9
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		326.6	292.5
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	[1]	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	[1]	326.6	292.5
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | 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] | 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		28.3	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	[1]	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	[1]	0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | 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] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		28.3	8.5
Entergy Arkansas [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		884.3	834.7
Entergy Arkansas [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		900.9	851.3
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	[1]	10.7	3.6
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	[1]	328	309.3
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]	545.6	521.8
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		4.7	7.1
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		3.6	4.1
Entergy Arkansas [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		8.3	5.4
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		148.7	127.3
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	[1]	10.7	3.6
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	[1]	129.7	112.5
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		4.7	7.1
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		3.6	4.1
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		198.3	196.8
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	[1]	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	[1]	198.3	196.8
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		8.3	5.4
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	[1]	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	[1]	0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Storm Reserve Escrow Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		8.3	5.4
Entergy New Orleans [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		60.7	103
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		153.4	194.6
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		86.4	88.6
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		1.1	1.7
Entergy New Orleans [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			0.2
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		5.2	1.1
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		60.7	103
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		148.2	193.5
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		86.4	88.6
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		1.1	1.7
Entergy New Orleans [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			0.2
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] | 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] | 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 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		5.2	1.1
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] | 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 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		5.2	1.1
Entergy Texas [Member]
Assets at fair value on a recurring basis
Temporary cash investments			5
Entergy Texas [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		34.2	45.6
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		28.7	37.5
Entergy Texas [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		5.5	3.1
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member]
Assets at fair value on a recurring basis
Temporary cash investments			5
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		28.7	42.5
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		28.7	37.5
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]
Assets at fair value on a recurring basis
Temporary cash investments			0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member]
Assets at fair value on a recurring basis
Temporary cash investments			0
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		5.5	3.1
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Securitization Recovery Trust Account [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		5.5	3.1
System Energy [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		839.4	780.5
System Energy [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		337	245.1
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,176.4	1,025.6
System Energy [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	1.6	0.3
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]	322.5	306.6
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]	515.3	473.6
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		337	245.1
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		547.5	493.7
System Energy [Member] | Fair Value Inputs Level 1 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	1.6	0.3
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]	208.9	248.3
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		113.6	58.3
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]	113.6	58.3
System Energy [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0	0
System Energy [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	0	0
System Energy [Member] | Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	$ 0	$ 0
[1]	(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements for additional information on the investment portfolios.(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 Valu60

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, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Issuance of Fixed Transmission Rights	$ 0	$ 0	$ 0	$ 0
Electricity Swaps And Options [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value, Measurement With Unobservable Inputs Reconciliation, Recurring Basis, Asset and Liability, Realized Gain (Loss) Included In Earnings	4	(9)	4	(9)
Fair Value Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset and Liability, Purchases	0	0	0	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	5	183	5	189
Unrealized losses included in OCI	43	(53)	93	86
Included as a regulatory liability/asset	0	0	0	0
Settlements	(14)	(55)	(64)	(200)
Balance as of June 30,	38	66	38	66
Fixed Transmission Rights (FTRs) [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value, Measurement With Unobservable Inputs Reconciliation, Recurring Basis, Asset and Liability, Realized Gain (Loss) Included In Earnings	0	0	0	0
Issuance of Fixed Transmission Rights	62	55	62	55
Fair Value Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset and Liability, Purchases	0	0	0	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	8	9	21	23
Unrealized losses included in OCI	0	0	0	0
Included as a regulatory liability/asset	31	20	48	27
Settlements	(44)	(38)	(74)	(59)
Balance as of June 30,	57	46	57	46
Fixed Transmission Rights (FTRs) [Member] | Entergy Arkansas [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Issuance of Fixed Transmission Rights	8.9	18.8	8.9	18.8
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	0.9	3.7	5.4	7.9
Unrealized gains included as a regulatory liability/asset	9	(3)	9.1	0.6
Settlements	(10.5)	(5.5)	(15.1)	(13.3)
Balance as of June 30,	8.3	14	8.3	14
Fixed Transmission Rights (FTRs) [Member] | Entergy Louisiana [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Issuance of Fixed Transmission Rights	31	18.1	31	18.1
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	4.1	3.3	8.5	8.5
Unrealized gains included as a regulatory liability/asset	7.5	16.4	18.3	21.7
Settlements	(14.3)	(21.6)	(29.5)	(32.1)
Balance as of June 30,	28.3	16.2	28.3	16.2
Fixed Transmission Rights (FTRs) [Member] | Entergy Mississippi [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Issuance of Fixed Transmission Rights	9.6	5.9	9.6	5.9
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	1.3	0.9	3.2	2.4
Unrealized gains included as a regulatory liability/asset	6.7	2.4	7.9	1.7
Settlements	(8.5)	(3.6)	(11.6)	(4.4)
Balance as of June 30,	9.1	5.6	9.1	5.6
Fixed Transmission Rights (FTRs) [Member] | Entergy New Orleans [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Issuance of Fixed Transmission Rights	5	2.8	5	2.8
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	0.5	0.6	1.1	1.5
Unrealized gains included as a regulatory liability/asset	3.1	0	4.8	(0.4)
Settlements	(3.4)	(1.4)	(5.7)	(1.9)
Balance as of June 30,	5.2	2	5.2	2
Fixed Transmission Rights (FTRs) [Member] | Entergy Texas [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Issuance of Fixed Transmission Rights	7.1	9.3	7.1	9.3
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	1	0.9	3.1	2.2
Unrealized gains included as a regulatory liability/asset	4.3	3.2	7.4	3.4
Settlements	(6.9)	(5.4)	(12.1)	(6.9)
Balance as of June 30,	$ 5.5	$ 8	$ 5.5	$ 8

Risk Management and Fair Valu61

Risk Management and Fair Values (Schedules Of Valuation Techniques) (Details) $ in Millions	Jun. 30, 2017USD ($)
Range from Average Percentage for Fair Value of Electricity Swaps	4.00%
Effect of Significant Unobservable Inputs on Fair Value of Electricity Swaps	$ 3
Fair Value of Electricity Swaps	$ 38

Decommissioning Trust Funds (Na

Decommissioning Trust Funds (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016	Mar. 31, 2017	Jan. 31, 2017
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts			$ 441		$ 399
Amortized cost of debt securities	$ 2,378		$ 2,378		2,212
Average coupon rate of debt securities	3.21%		3.21%
Average duration of debt securities, years			6 years 51 days
Average maturity of debt securities, years			9 years 350 days
Proceeds from the dispositions of debt securities	$ 949	$ 504	$ 1,463	$ 1,233
Gains from dispositions of debt securities, gross	61	10	70	20
Losses from dispositions of debt securities, gross	2	2	7	5
Entergy Arkansas [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 327		$ 327		310.1
Average coupon rate of debt securities	2.53%		2.53%
Average duration of debt securities, years			5 years 303 days
Average maturity of debt securities, years			6 years 318 days
Proceeds from the dispositions of debt securities	$ 131.3	45.2	$ 167.3	103.8
Gains from dispositions of debt securities, gross	11.2	0.4	11.7	1.2
Losses from dispositions of debt securities, gross	0.1	0.2	$ 0.2	0.3
Entergy Louisiana [Member]
Decommissioning Trust Funds [Abstract]
Percentage Interest in River Bend			30.00%
Amortized cost of debt securities	$ 456.1		$ 456.1		421.9
Average coupon rate of debt securities	3.79%		3.79%
Average duration of debt securities, years			5 years 292 days
Average maturity of debt securities, years			11 years 179 days
Proceeds from the dispositions of debt securities	$ 85	69.7	$ 125.6	123.5
Gains from dispositions of debt securities, gross	5	1.7	5	2.6
Losses from dispositions of debt securities, gross	0.1	0	0.3	0.1
System Energy [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 321.5		$ 321.5		$ 309.1
Average coupon rate of debt securities	2.37%		2.37%
Average duration of debt securities, years			6 years 164 days
Average maturity of debt securities, years			8 years 307 days
Proceeds from the dispositions of debt securities	$ 177.7	100.9	$ 253.5	289.4
Gains from dispositions of debt securities, gross	0.4	0.9	0.5	2.5
Losses from dispositions of debt securities, gross	0.6	$ 0.1	1.3	$ 0.4
Fitzpatrick [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value						$ 805	$ 793
Indian Point 3 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	758		758				$ 726
Indian Point 1 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	465		465
Indian Point 2 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	591		591
Palisades [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	434		434
Pilgrim [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	1,010		1,010
Vermont Yankee [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	$ 595		$ 595

Decommissioning Trust Funds (Se

Decommissioning Trust Funds (Securities Held) (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Schedule of Available-for-sale Securities [Line Items]
Fair Value	$ 6,797	$ 5,724
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	1,902	1,707
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	16	28
Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	4,389	3,511
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	1,857	1,673
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	1	1
Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	2,408	2,213
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	45	34
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	15	27
Entergy Arkansas [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	884.3	834.7
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	311.3	284.9
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	2.3	4.2
Entergy Arkansas [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	556.3	525.4
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	308	281.5
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0	0
Entergy Arkansas [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	328	309.3
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	3.3	3.4
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	2.3	4.2
Entergy Louisiana [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	1,220.7	1,140.7
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	406.5	354.6
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	2.9	5
Entergy Louisiana [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	756.6	715.9
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	395.6	346.6
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0	0
Entergy Louisiana [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	464.1	424.8
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	10.9	8
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	2.9	5
System Energy [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	839.4	780.5
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	260.9	223.9
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	2.3	4.6
System Energy [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	516.9	473.9
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	257.6	221.9
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0	0.1
System Energy [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	322.5	306.6
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	3.3	2
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	$ 2.3	$ 4.5

Decommissioning Trust Funds (Av

Decommissioning Trust Funds (Available For Sale Securities Continuous Unrealized Loss Position Fair Value) (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	$ 2	$ 23
More than 12 months Fair Value	0	1
Total Fair Value	2	24
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	1	1
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	1
Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	997	1,169
More than 12 months Fair Value	47	20
Total Fair Value	1,044	1,189
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	12	26
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	3	1
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	15	27
Entergy Arkansas [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	0	0
More than 12 months Fair Value	0	0
Total Fair Value	0	0
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0	0
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
Entergy Arkansas [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	118.1	146.7
More than 12 months Fair Value	10.1	0
Total Fair Value	128.2	146.7
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	1.7	4.2
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.6	0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	2.3	4.2
Entergy Louisiana [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	0	0
More than 12 months Fair Value	0	0
Total Fair Value	0	0
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0	0
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
Entergy Louisiana [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	164.4	198.8
More than 12 months Fair Value	9.7	4.8
Total Fair Value	174.1	203.6
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	2.4	4.8
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.5	0.2
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	2.9	5
System Energy [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	0	0
More than 12 months Fair Value	0	0
Total Fair Value	0	0
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0	0
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	0.1
System Energy [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	199.5	220.9
More than 12 months Fair Value	8.6	0.8
Total Fair Value	208.1	221.7
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	2	4.4
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.3	0.1
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	$ 2.3	$ 4.5

Decommissioning Trust Funds (Fa

Decommissioning Trust Funds (Fair Value Of Debt Securities By Contractual Maturities) (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Fair value of debt securities by contractual maturities
Less than 1 year	$ 106	$ 125
1 year - 5 years	805	763
5 years - 10 years	795	719
10 years - 15 years	111	109
15 years - 20 years	88	73
20 years+	503	424
Total	2,408	2,213
Entergy Arkansas [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	16.8	16.7
1 year - 5 years	102.6	106.2
5 years - 10 years	183.5	161.2
10 years - 15 years	4.4	7.7
15 years - 20 years	1.1	1
20 years+	19.6	16.5
Total	328	309.3
Entergy Louisiana [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	28.5	31.4
1 year - 5 years	105.2	99.1
5 years - 10 years	131.9	122.8
10 years - 15 years	44.3	41.4
15 years - 20 years	38.6	30.9
20 years+	115.6	99.2
Total	464.1	424.8
System Energy [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	8.6	6.6
1 year - 5 years	159.6	188.2
5 years - 10 years	86.4	78.5
10 years - 15 years	2.3	1.3
15 years - 20 years	7.8	7.8
20 years+	57.8	24.2
Total	$ 322.5	$ 306.6

Income Taxes Income Taxes (Narr

Income Taxes Income Taxes (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Jun. 30, 2017	Mar. 31, 2017
Reduction in income tax expense related to permanent difference for nuclear decommissioning liability, net of unrecognized tax benefits	$ 373
Write-off of deferred tax asset resulting from implementation of accounting standard		$ 11.5
Fitzpatrick [Member]
Income tax benefit resulting from sale of FitzPatrick		$ 44

Property, Plant, And Equipment

Property, Plant, And Equipment (Narrative) (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Construction expenditures in accounts payable	$ 198	$ 253
Entergy Arkansas [Member]
Construction expenditures in accounts payable	47.8	40.9
Entergy Louisiana [Member]
Construction expenditures in accounts payable	55.1	114.8
Entergy Mississippi [Member]
Construction expenditures in accounts payable	5.3	11.5
Entergy New Orleans [Member]
Construction expenditures in accounts payable	1.1	2.3
Entergy Texas [Member]
Construction expenditures in accounts payable	15.2	9.3
System Energy [Member]
Construction expenditures in accounts payable	$ 28.1	$ 6.2

Variable Interest Entities (Nar

Variable Interest Entities (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Mar. 31, 2016	Jun. 30, 2017	Jun. 30, 2016
Waterford Three [Member] | Entergy Louisiana [Member]
Variable Interest Entity [Line Items]
Payments on lease, including interest	$ 9.2
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	$ 8.6
Percentage in power plant owned by VIE		11.50%

Dispositions Dispositions (Narr

Dispositions Dispositions (Narrative) (Details)	1 Months Ended		3 Months Ended			6 Months Ended
	Mar. 31, 2017USD ($)MW	Aug. 31, 2016USD ($)	Jun. 30, 2017USD ($)	Mar. 31, 2017USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2016USD ($)
Payments to Acquire Property, Plant, and Equipment						$ 0	$ (947,903,000)
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property			$ 0		$ 0	(16,270,000)	0
Fitzpatrick [Member]
Capacity Of Power Plant Unit | MW	838
Proceeds from Divestiture of Businesses	$ 110,000,000
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property	(16,000,000)
Cost of Reimbursable Expense	8,000,000
Non-refundable signing fee paid upon agreement and assumption by Exelon of certain liabilities		$ 10,000,000
Income tax benefit resulting from sale of FitzPatrick				$ 44,000,000
Decommissioning Fund Investments, Fair Value	805,000,000			805,000,000
Asset Retirement Obligation	727,000,000			727,000,000
Other operation and maintenance expense reimbursement				98,000,000
Reimbursement Revenue				7,000,000
Reimbursement for taxes other than income taxes				3,000,000
Nuclear defueling credit				10,000,000
Net Book Value	$ 0			$ 0
Entergy Arkansas [Member]
Payments to Acquire Property, Plant, and Equipment						0	(236,969,000)
Entergy Louisiana [Member]
Payments to Acquire Property, Plant, and Equipment						0	(473,956,000)
Entergy New Orleans [Member]
Payments to Acquire Property, Plant, and Equipment						$ 0	$ (236,978,000)

Asset Retirement Obligations 70

Asset Retirement Obligations Asset Retirement Obligations (Narrative) (Details) $ in Millions	Jun. 30, 2017USD ($)
System Energy [Member]
Reduction in decommissioning liability	$ 35.9