Entergy Louisiana, LLC COLLATERAL TR MT (ELC) 10-Q 4 May 18 2018 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2018	Apr. 30, 2018
Entity Registrant Name	ENTERGY CORP /DE/
Entity Central Index Key	65,984
Document Type	10-Q
Document Period End Date	Mar. 31, 2018
Amendment Flag	false
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		180,823,624
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, LLC
Entity Central Index Key	71,508
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Entergy Texas [Member]
Entity Registrant Name	ENTERGY TEXAS, INC.
Entity Central Index Key	1,427,437
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
System Energy [Member]
Entity Registrant Name	SYSTEM ENERGY RESOURCES, INC.
Entity Central Index Key	202,584
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer

Consolidated Statements Of Inco

Consolidated Statements Of Income - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2018	Mar. 31, 2017
OPERATING REVENUES
Electric		$ 2,248,262	$ 1,991,740
Natural gas		56,695	43,351
Competitive businesses		418,924	553,367
TOTAL		2,723,881	2,588,458
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		443,296	417,566
Purchased power		396,023	357,768
Nuclear refueling outage expenses		42,760	42,564
Other operation and maintenance		783,585	846,856
Asset Write-Offs, Impairments, And Related Charges		72,924	211,791
Decommissioning		94,400	114,374
Taxes other than income taxes		165,218	156,353
Depreciation and amortization		347,065	347,265
Other regulatory charges (credits) - net		42,946	(85,302)
TOTAL		2,388,217	2,409,235
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property		0	(16,270)
OPERATING INCOME		335,664	195,493
OTHER INCOME
Allowance for equity funds used during construction		28,343	19,008
Investment Income, Net		16,870	56,549
Miscellaneous - net		(31,356)	(15,189)
TOTAL		13,857	60,368
INTEREST EXPENSE
Interest expense		182,923	171,089
Allowance for borrowed funds used during construction		(13,265)	(9,042)
TOTAL		169,658	162,047
INCOME BEFORE INCOME TAXES		179,863	93,814
Income taxes		43,663	7,763
CONSOLIDATED NET INCOME	[1]	136,200	86,051
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders		3,439	3,446
EARNINGS APPLICABLE TO COMMON STOCK		$ 132,761	$ 82,605
Earnings per average common share:
Basic (in dollars per share)		$ 0.7346731314	$ 0.46
Diluted (in dollars per share)		0.73	0.46
Dividends declared per common share (in dollars per share)		$ 0.89	$ 0.87
Basic average number of common shares outstanding (in shares)		180,707,575	179,335,063
Diluted average number of common shares outstanding (in shares)		181,431,968	179,842,053
Entergy Arkansas [Member]
OPERATING REVENUES
Electric		$ 551,024	$ 474,351
Natural gas		0
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		108,306	99,409
Purchased power		71,972	55,133
Nuclear refueling outage expenses		23,402	19,619
Other operation and maintenance		169,358	163,008
Decommissioning		14,760	13,895
Taxes other than income taxes		27,905	24,051
Depreciation and amortization		71,981	67,066
Other regulatory charges (credits) - net		(3,307)	(10,526)
TOTAL		484,377	431,655
OPERATING INCOME		66,647	42,696
OTHER INCOME
Allowance for equity funds used during construction		4,008	4,350
Investment Income, Net		6,814	6,932
Miscellaneous - net		(3,871)	(2,956)
TOTAL		6,951	8,326
INTEREST EXPENSE
Interest expense		29,766	27,252
Allowance for borrowed funds used during construction		(1,890)	(1,962)
TOTAL		27,876	25,290
INCOME BEFORE INCOME TAXES		45,722	25,732
Income taxes		9,467	11,428
CONSOLIDATED NET INCOME		36,255	14,304
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders		357	357
EARNINGS APPLICABLE TO COMMON STOCK		35,898	13,947
Entergy Louisiana [Member]
OPERATING REVENUES
Electric		1,005,106	864,076
Natural gas		24,238	16,707
TOTAL		1,029,344	880,783
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		180,781	154,044
Purchased power		251,772	239,827
Nuclear refueling outage expenses		13,099	12,185
Other operation and maintenance		234,380	217,112
Decommissioning		12,772	12,123
Taxes other than income taxes		51,280	45,283
Depreciation and amortization		120,822	115,630
Other regulatory charges (credits) - net		23,119	(74,187)
TOTAL		888,025	722,017
OPERATING INCOME		141,319	158,766
OTHER INCOME
Allowance for equity funds used during construction		17,745	9,990
Investment Income, Net		43,275	39,830
Miscellaneous - net		(7,665)	(9,142)
TOTAL		53,355	40,678
INTEREST EXPENSE
Interest expense		70,096	67,315
Allowance for borrowed funds used during construction		(8,763)	(5,174)
TOTAL		61,333	62,141
INCOME BEFORE INCOME TAXES		133,341	137,303
Income taxes		21,748	42,925
CONSOLIDATED NET INCOME		111,593	94,378
Entergy Mississippi [Member]
OPERATING REVENUES
Electric		315,743	258,443
Natural gas		0
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		63,528	39,140
Purchased power		87,456	71,070
Other operation and maintenance		59,458	54,622
Taxes other than income taxes		25,394	23,972
Depreciation and amortization		38,182	35,317
Other regulatory charges (credits) - net		293	(5,837)
TOTAL		274,311	218,284
OPERATING INCOME		41,432	40,159
OTHER INCOME
Allowance for equity funds used during construction		1,978	1,843
Investment Income, Net		25	26
Miscellaneous - net		(571)	(976)
TOTAL		1,432	893
INTEREST EXPENSE
Interest expense		13,905	12,672
Allowance for borrowed funds used during construction		(828)	(720)
TOTAL		13,077	11,952
INCOME BEFORE INCOME TAXES		29,787	29,100
Income taxes		6,944	11,942
CONSOLIDATED NET INCOME		22,843	17,158
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders		238	238
EARNINGS APPLICABLE TO COMMON STOCK		22,605	16,920
Entergy New Orleans [Member]
OPERATING REVENUES
Electric		155,818	142,345
Natural gas		32,457	26,644
TOTAL		188,275	168,989
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		23,739	30,075
Purchased power		83,156	68,359
Other operation and maintenance		28,299	22,291
Taxes other than income taxes		15,132	12,846
Depreciation and amortization		13,747	13,050
Other regulatory charges (credits) - net		6,333	385
TOTAL		170,406	147,006
OPERATING INCOME		17,869	21,983
OTHER INCOME
Allowance for equity funds used during construction		851	450
Investment Income, Net		93	135
Miscellaneous - net		(337)	(123)
TOTAL		607	462
INTEREST EXPENSE
Interest expense		5,279	5,343
Allowance for borrowed funds used during construction		(314)	(158)
TOTAL		4,965	5,185
INCOME BEFORE INCOME TAXES		13,511	17,260
Income taxes		2,629	6,282
CONSOLIDATED NET INCOME		10,882	10,978
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders		0	241
EARNINGS APPLICABLE TO COMMON STOCK		10,882	10,737
Entergy Texas [Member]
OPERATING REVENUES
Electric		348,940	363,927
Natural gas		0
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		18,706	58,013
Purchased power		159,692	150,384
Other operation and maintenance		52,674	54,128
Taxes other than income taxes		20,403	19,444
Depreciation and amortization		30,766	28,111
Other regulatory charges (credits) - net		25,617	15,227
TOTAL		307,858	325,307
OPERATING INCOME		41,082	38,620
OTHER INCOME
Allowance for equity funds used during construction		1,661	1,281
Investment Income, Net		555	201
Miscellaneous - net		113	40
TOTAL		2,329	1,522
INTEREST EXPENSE
Interest expense		22,051	21,808
Allowance for borrowed funds used during construction		(938)	(761)
TOTAL		21,113	21,047
INCOME BEFORE INCOME TAXES		22,298	19,095
Income taxes		4,948	8,241
CONSOLIDATED NET INCOME		17,350	10,854
System Energy [Member]
OPERATING REVENUES
Electric		148,443	154,787
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		28,425	15,334
Nuclear refueling outage expenses		3,972	4,773
Other operation and maintenance		45,339	47,463
Decommissioning		8,457	13,232
Taxes other than income taxes		7,097	6,424
Depreciation and amortization		33,321	35,441
Other regulatory charges (credits) - net		(9,109)	(10,362)
TOTAL		117,502	112,305
OPERATING INCOME		30,941	42,482
OTHER INCOME
Allowance for equity funds used during construction		2,100	1,094
Investment Income, Net		6,886	4,674
Miscellaneous - net		(1,176)	(1,066)
TOTAL		7,810	4,702
INTEREST EXPENSE
Interest expense		9,325	9,119
Allowance for borrowed funds used during construction		(532)	(267)
TOTAL		8,793	8,852
INCOME BEFORE INCOME TAXES		29,958	38,332
Income taxes		7,650	17,985
CONSOLIDATED NET INCOME		$ 22,308	$ 20,347
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Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2018	Mar. 31, 2017
OPERATING ACTIVITIES
Consolidated net income	[1]	$ 136,200	$ 86,051
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		525,181	531,373
Deferred income taxes, investment tax credits, and non-current taxes accrued		104,607	16,497
Impairment of Long-Lived Assets Held-for-use		25,800	145,026
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property		0	(16,270)
Changes in working capital:
Receivables		131,150	156,201
Fuel inventory		(16,261)	6,465
Accounts payable		(68,857)	(47,682)
Taxes accrued		(56,301)	(58,832)
Interest accrued		(10,011)	(13,921)
Deferred fuel costs		(76,238)	(7,389)
Other working capital accounts		(28,004)	(7,324)
Changes in provisions for estimated losses		10,744	(4,031)
Changes in other regulatory assets		84,349	47,497
Increase (Decrease) in Regulatory Liabilities		(31,380)	(18,324)
Changes in pensions and other postretirement liabilities		(97,418)	(86,430)
Other Noncash Income (Expense)		(76,168)	(199,514)
Net cash flow provided by operating activities		557,393	529,393
INVESTING ACTIVITIES
Construction/capital expenditures		(931,479)	(794,448)
Allowance for equity funds used during construction		28,512	19,254
Nuclear fuel purchases		(49,647)	(137,613)
Payments for Nuclear Fuel		(49,647)	(137,613)
Payments to storm reserve escrow account		(1,175)	(480)
Receipts from storm reserve escrow account		0	8,836
Increases in other investments		(406)	(10,377)
Proceeds from Sale of Productive Assets		0	100,000
Proceeds from nuclear decommissioning trust fund sales		1,091,332	513,750
Investment in nuclear decommissioning trust funds		(1,106,094)	(556,161)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		0	25,493
Proceeds from insurance		1,582	20,909
Changes in securitization account		(7,063)	(963)
Net cash flow used in investing activities		(974,438)	(811,800)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		2,505,726	236,198
Common stock and treasury stock		1,952	2,448
Retirement of long-term debt		(734,000)	(811,690)
Changes in credit borrowings and commercial paper - net		(773,177)	908,378
Dividends paid:
Common stock		(160,887)	(156,073)
Preferred stock	[1]	(3,439)	(3,446)
Other		5,193	1,810
Net cash flow provided by financing activities		841,368	177,625
Net increase (decrease) in cash and cash equivalents		424,323	(104,782)
Cash and cash equivalents at beginning of period		781,273	1,187,844
Cash and cash equivalents at end of period		1,205,596	1,083,062
Cash paid / (received) during the period for:
Interest - net of amount capitalized		185,606	178,134
Income taxes		(4,297)	(18,044)
Entergy Arkansas [Member]
OPERATING ACTIVITIES
Consolidated net income		36,255	14,304
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		115,976	105,721
Deferred income taxes, investment tax credits, and non-current taxes accrued		11,877	16,361
Changes in working capital:
Receivables		31,033	53,355
Fuel inventory		(13,868)	(5,747)
Accounts payable		(26,924)	(73,635)
Taxes accrued		10,072	7,175
Interest accrued		9,748	8,562
Deferred fuel costs		1,971	(9,137)
Other working capital accounts		5,591	15,485
Changes in provisions for estimated losses		6,520	1,997
Changes in other regulatory assets		13,835	1,815
Increase (Decrease) in Regulatory Liabilities		(13,546)	23,435
Changes in pensions and other postretirement liabilities		(19,277)	(19,553)
Other Noncash Income (Expense)		10,627	14,403
Net cash flow provided by operating activities		179,890	154,541
INVESTING ACTIVITIES
Construction/capital expenditures		(167,485)	(165,496)
Allowance for equity funds used during construction		4,143	4,557
Nuclear fuel purchases		(19,391)	(88,537)
Payments for Nuclear Fuel		(19,391)	(88,537)
Proceeds from sale of nuclear fuel		30,907	51,029
Proceeds from nuclear decommissioning trust fund sales		34,865	36,013
Investment in nuclear decommissioning trust funds		(40,238)	(40,961)
Changes in securitization account		(4,145)	(3,702)
Net cash flow used in investing activities		(161,344)	(207,097)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		175,000	0
Retirement of long-term debt		(149,904)	0
Change in money pool payable - net		(42,279)	(20,224)
Changes in credit borrowings and commercial paper - net		(6,087)	52,300
Dividends paid:
Preferred stock		(357)	(357)
Other		(212)	803
Net cash flow provided by financing activities		(23,839)	32,522
Net increase (decrease) in cash and cash equivalents		(5,293)	(20,034)
Cash and cash equivalents at beginning of period		6,216	20,509
Cash and cash equivalents at end of period		923	475
Cash paid / (received) during the period for:
Interest - net of amount capitalized		18,761	17,311
Entergy Louisiana [Member]
OPERATING ACTIVITIES
Consolidated net income		111,593	94,378
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		157,887	151,472
Deferred income taxes, investment tax credits, and non-current taxes accrued		86,443	163,299
Changes in working capital:
Receivables		53,786	75,196
Fuel inventory		(1,402)	3,066
Accounts payable		(18,036)	(7,846)
Taxes accrued		(24,705)	22,563
Interest accrued		6,365	5,983
Deferred fuel costs		(52,090)	(19,487)
Other working capital accounts		(55)	(20,810)
Changes in provisions for estimated losses		(481)	(4,059)
Changes in other regulatory assets		28,579	28,922
Increase (Decrease) in Regulatory Liabilities		(6,088)	(59,969)
Changes in pensions and other postretirement liabilities		(18,075)	(17,054)
Other Noncash Income (Expense)		4,319	(75,950)
Net cash flow provided by operating activities		328,040	339,704
INVESTING ACTIVITIES
Construction/capital expenditures		(469,398)	(360,693)
Allowance for equity funds used during construction		17,745	9,990
Change in money pool receivable - net		(170,163)	(8,047)
Nuclear fuel purchases		(9,997)	(139,620)
Payments for Nuclear Fuel		(9,997)	(139,620)
Proceeds from sale of nuclear fuel		36,301	28,884
Payments to storm reserve escrow account		(853)	(332)
Receipts from storm reserve escrow account		0	8,836
Proceeds from nuclear decommissioning trust fund sales		125,453	40,586
Investment in nuclear decommissioning trust funds		(137,097)	(51,393)
Proceeds from insurance		1,582	5,305
Changes in securitization account		(7,523)	(5,527)
Net cash flow used in investing activities		(613,950)	(472,011)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		947,038	0
Retirement of long-term debt		(154,117)	(57,499)
Changes in credit borrowings and commercial paper - net		19,382	87,504
Dividends paid:
Common stock		0	(42,125)
Other		(14)	(2,130)
Net cash flow provided by financing activities		812,289	(14,250)
Net increase (decrease) in cash and cash equivalents		526,379	(146,557)
Cash and cash equivalents at beginning of period		35,907	213,850
Cash and cash equivalents at end of period		562,286	67,293
Cash paid / (received) during the period for:
Interest - net of amount capitalized		61,613	59,261
Income taxes		(2,973)	(116,937)
Entergy Mississippi [Member]
OPERATING ACTIVITIES
Consolidated net income		22,843	17,158
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		38,182	35,317
Deferred income taxes, investment tax credits, and non-current taxes accrued		7,787	13,505
Changes in working capital:
Receivables		1,018	17,890
Fuel inventory		(767)	2,672
Accounts payable		(24,818)	(19,639)
Taxes accrued		(56,244)	(38,825)
Interest accrued		(5,548)	(2,953)
Deferred fuel costs		13,817	(5,236)
Other working capital accounts		(4,856)	(578)
Changes in provisions for estimated losses		4,754	(1,772)
Changes in other regulatory assets		4,586	(10,918)
Increase (Decrease) in Regulatory Liabilities		766	(3,341)
Changes in pensions and other postretirement liabilities		(4,604)	(4,613)
Other Noncash Income (Expense)		(5,757)	(7,799)
Net cash flow provided by operating activities		(8,841)	(9,132)
INVESTING ACTIVITIES
Construction/capital expenditures		(79,141)	(92,087)
Allowance for equity funds used during construction		1,978	1,843
Change in money pool receivable - net		1,633	10,595
Increases in other investments		(738)	(42)
Net cash flow used in investing activities		(76,268)	(79,691)
Proceeds from the issuance of:
Change in money pool payable - net		74,892	12,324
Dividends paid:
Preferred stock		(238)	(238)
Other		4,662	(50)
Net cash flow provided by financing activities		79,316	12,036
Net increase (decrease) in cash and cash equivalents		(5,793)	(76,787)
Cash and cash equivalents at beginning of period		6,096	76,834
Cash and cash equivalents at end of period		303	47
Cash paid / (received) during the period for:
Interest - net of amount capitalized		18,820	15,036
Income taxes		0	(15,087)
Entergy New Orleans [Member]
OPERATING ACTIVITIES
Consolidated net income		10,882	10,978
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		13,747	13,050
Deferred income taxes, investment tax credits, and non-current taxes accrued		17,909	7,102
Changes in working capital:
Receivables		3,378	(2,659)
Fuel inventory		951	1,798
Accounts payable		(7,973)	(11,920)
Taxes accrued		(13,351)	(1,992)
Interest accrued		(81)	34
Deferred fuel costs		(11,309)	6,096
Other working capital accounts		(12,082)	(13,106)
Changes in provisions for estimated losses		196	(655)
Changes in other regulatory assets		7,226	300
Increase (Decrease) in Regulatory Liabilities		1,331	(934)
Changes in pensions and other postretirement liabilities		(3,686)	(3,915)
Other Noncash Income (Expense)		(89)	1,442
Net cash flow provided by operating activities		7,049	5,619
INVESTING ACTIVITIES
Construction/capital expenditures		(41,105)	(26,079)
Allowance for equity funds used during construction		851	450
Change in money pool receivable - net		12,291	(12,100)
Payments to storm reserve escrow account		(232)	(110)
Receipts from storm reserve escrow account		3	0
Changes in securitization account		(3,381)	(2,912)
Net cash flow used in investing activities		(31,573)	(40,751)
Dividends paid:
Common stock		(6,250)	(12,200)
Preferred stock		0	(241)
Other		(607)	573
Net cash flow provided by financing activities		(6,857)	(11,868)
Net increase (decrease) in cash and cash equivalents		(31,381)	(47,000)
Cash and cash equivalents at beginning of period		32,741	103,068
Cash and cash equivalents at end of period		1,360	56,068
Cash paid / (received) during the period for:
Interest - net of amount capitalized		5,098	5,043
Entergy Texas [Member]
OPERATING ACTIVITIES
Consolidated net income		17,350	10,854
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		30,766	28,111
Deferred income taxes, investment tax credits, and non-current taxes accrued		(21,607)	(25,678)
Changes in working capital:
Receivables		9,190	(683)
Fuel inventory		(134)	4,581
Accounts payable		(24,653)	(1,150)
Taxes accrued		3,981	16,110
Interest accrued		(5,575)	(6,816)
Deferred fuel costs		(28,626)	20,375
Other working capital accounts		4,788	1,422
Changes in provisions for estimated losses		(208)	663
Changes in other regulatory assets		20,497	23,762
Increase (Decrease) in Regulatory Liabilities		5,145	(2,498)
Changes in pensions and other postretirement liabilities		(6,851)	(5,814)
Other Noncash Income (Expense)		(3,015)	(3,659)
Net cash flow provided by operating activities		1,048	59,580
INVESTING ACTIVITIES
Construction/capital expenditures		(94,123)	(68,765)
Allowance for equity funds used during construction		1,696	1,320
Change in money pool receivable - net		32,313	681
Increases in other investments		0	(14,000)
Changes in securitization account		7,985	11,177
Net cash flow used in investing activities		(52,129)	(69,587)
Proceeds from the issuance of:
Retirement of long-term debt		(24,977)	(24,188)
Change in money pool payable - net		0	28,941
Dividends paid:
Other		(479)	(839)
Net cash flow provided by financing activities		(25,456)	3,914
Net increase (decrease) in cash and cash equivalents		(76,537)	(6,093)
Cash and cash equivalents at beginning of period		115,513	6,181
Cash and cash equivalents at end of period		38,976	88
Cash paid / (received) during the period for:
Interest - net of amount capitalized		26,939	27,986
Income taxes		(1,624)	(3,446)
System Energy [Member]
OPERATING ACTIVITIES
Consolidated net income		22,308	20,347
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		66,323	61,562
Deferred income taxes, investment tax credits, and non-current taxes accrued		7,929	18,293
Changes in working capital:
Receivables		5,883	13,953
Accounts payable		(9,632)	(3,008)
Taxes accrued		(15,033)	(15,032)
Interest accrued		736	295
Other working capital accounts		(5,874)	(1,111)
Changes in other regulatory assets		(1,960)	(1,571)
Increase (Decrease) in Regulatory Liabilities		(18,988)	23,401
Changes in pensions and other postretirement liabilities		(3,537)	(4,187)
Other Noncash Income (Expense)		17,216	(47,166)
Net cash flow provided by operating activities		65,371	65,776
INVESTING ACTIVITIES
Construction/capital expenditures		(30,707)	(14,096)
Allowance for equity funds used during construction		2,100	1,094
Change in money pool receivable - net		21,531	(80,744)
Nuclear fuel purchases		(74,257)	(21,765)
Payments for Nuclear Fuel		(74,257)	(21,765)
Proceeds from sale of nuclear fuel		0	60,188
Proceeds from nuclear decommissioning trust fund sales		54,210	75,787
Investment in nuclear decommissioning trust funds		(58,833)	(85,532)
Net cash flow used in investing activities		(85,956)	(65,068)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt		100,000	0
Retirement of long-term debt		(50,002)	(50,001)
Changes in credit borrowings and commercial paper - net		25,339	43,851
Dividends paid:
Common stock		(63,240)	0
Other		0	(13)
Net cash flow provided by financing activities		12,097	(6,163)
Net increase (decrease) in cash and cash equivalents		(8,488)	(5,455)
Cash and cash equivalents at beginning of period		287,187	245,863
Cash and cash equivalents at end of period		278,699	240,408
Cash paid / (received) during the period for:
Interest - net of amount capitalized		$ 8,592	$ 8,593
[1]	Text selection found with no content.

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Cash and cash equivalents:
Cash	$ 57,921	$ 56,629
Temporary cash investments	1,147,675	724,644
Total cash and cash equivalents	1,205,596	781,273
Accounts receivable:
Customer	616,653	673,347
Allowance for doubtful accounts	(14,515)	(13,587)
Other	163,039	169,377
Accrued unbilled revenues	316,624	383,813
Total accounts receivable	1,081,801	1,212,950
Deferred fuel costs	83,445	95,746
Fuel inventory - at average cost	198,904	182,643
Materials and supplies - at average cost	741,677	723,222
Deferred nuclear refueling outage costs	112,365	133,164
Prepayments and other	231,946	156,333
TOTAL	3,655,734	3,285,331
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	198	198
Decommissioning trust funds	7,115,686	7,211,993
Non-utility property - at cost (less accumulated depreciation)	289,074	260,980
Other	433,868	441,862
TOTAL	7,838,826	7,915,033
PROPERTY, PLANT, AND EQUIPMENT
Electric	47,515,661	47,287,370
Property under capital lease	620,419	620,544
Natural gas	462,756	453,162
Construction work in progress	2,347,660	1,980,508
Nuclear fuel	857,893	923,200
TOTAL PROPERTY, PLANT, AND EQUIPMENT	51,804,389	51,264,784
Less - accumulated depreciation and amortization	21,701,715	21,600,424
PROPERTY, PLANT, AND EQUIPMENT - NET	30,102,674	29,664,360
Regulatory assets:
Other regulatory assets	4,851,338	4,935,689
Deferred fuel costs	239,347	239,298
Goodwill	377,172	377,172
Accumulated deferred income taxes	21,144	178,204
Other	195,290	112,062
TOTAL	5,684,291	5,842,425
TOTAL ASSETS	47,281,525	46,707,149
CURRENT LIABILITIES
Currently maturing long-term debt	1,260,008	760,007
Notes payable and commercial paper	805,131	1,578,308
Accounts payable	1,260,718	1,452,216
Customer deposits	403,072	401,330
Taxes Payable, Current	158,667	214,967
Interest accrued	177,961	187,972
Deferred fuel costs	58,032	146,522
Obligations under capital leases	1,419	1,502
Pension and other postretirement liabilities	63,612	71,612
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	912,103	0
Other	131,949	221,771
TOTAL	5,232,672	5,036,207
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	4,452,168	4,466,503
Accumulated deferred investment tax credits	217,502	219,634
Regulatory liability for income taxes - net	1,981,963	2,900,204
Obligations under capital leases	21,632	22,015
Other regulatory liabilities	1,563,278	1,588,520
Decommissioning and asset retirement cost liabilities	6,328,664	6,185,814
Accumulated provisions	489,026	478,273
Pension and other postretirement liabilities	2,821,236	2,910,654
Long-term debt	15,591,628	14,315,259
Other	409,014	393,748
TOTAL	33,876,111	33,480,624
Subsidiaries' preferred stock without sinking fund	197,799	197,803
Common Shareholders' Equity:
Common stock	2,548	2,548
Paid-in capital	5,417,263	5,433,433
Retained earnings	8,493,790	7,977,702
Accumulated other comprehensive loss	(561,498)	(23,531)
Less - treasury stock, at cost	5,377,160	5,397,637
TOTAL	7,974,943	7,992,515
TOTAL	7,974,943	7,992,515
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	47,281,525	46,707,149
Entergy Arkansas [Member]
Cash and cash equivalents:
Cash	891	6,184
Temporary cash investments	32	32
Total cash and cash equivalents	923	6,216
Securitization recovery trust account	7,893	3,748
Accounts receivable:
Customer	127,821	110,016
Allowance for doubtful accounts	(1,250)	(1,063)
Associated companies	34,105	38,765
Other	46,631	65,209
Accrued unbilled revenues	79,707	105,120
Total accounts receivable	287,014	318,047
Deferred fuel costs	61,282	63,302
Fuel inventory - at average cost	43,226	29,358
Materials and supplies - at average cost	198,585	192,853
Deferred nuclear refueling outage costs	49,047	56,485
Prepayments and other	9,597	12,108
TOTAL	657,567	682,117
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	935,728	944,890
Other	786	3,160
TOTAL	936,514	948,050
PROPERTY, PLANT, AND EQUIPMENT
Electric	11,111,420	11,059,538
Construction work in progress	361,843	280,888
Nuclear fuel	226,435	277,345
TOTAL PROPERTY, PLANT, AND EQUIPMENT	11,699,698	11,617,771
Less - accumulated depreciation and amortization	4,827,210	4,762,352
PROPERTY, PLANT, AND EQUIPMENT - NET	6,872,488	6,855,419
Regulatory assets:
Other regulatory assets	1,553,602	1,567,437
Deferred fuel costs	67,145	67,096
Other	20,397	13,910
TOTAL	1,641,144	1,648,443
TOTAL ASSETS	10,107,713	10,134,029
CURRENT LIABILITIES
Short-term borrowings	43,887	49,974
Associated companies accounts payable	308,104	365,915
Other	169,916	215,942
Customer deposits	97,885	97,687
Taxes Payable, Current	57,393	47,321
Interest accrued	27,963	18,215
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	386,489	0
Other	28,730	29,922
TOTAL	1,120,367	824,976
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	1,205,470	1,190,669
Accumulated deferred investment tax credits	33,803	34,104
Regulatory liability for income taxes - net	597,025	985,823
Other regulatory liabilities	352,354	363,591
Decommissioning and asset retirement cost liabilities	995,973	981,213
Accumulated provisions	41,249	34,729
Pension and other postretirement liabilities	334,016	353,274
Long-term debt	2,978,569	2,952,399
Other	4,885	5,147
TOTAL	6,543,344	6,900,949
Subsidiaries' preferred stock without sinking fund	31,350	31,350
Common Shareholders' Equity:
Common stock	470	470
Paid-in capital	790,264	790,264
Retained earnings	1,621,918	1,586,020
TOTAL	2,412,652	2,376,754
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	10,107,713	10,134,029
Entergy Louisiana [Member]
Cash and cash equivalents:
Cash	385	5,836
Temporary cash investments	561,901	30,071
Total cash and cash equivalents	562,286	35,907
Accounts receivable:
Customer	219,522	254,308
Allowance for doubtful accounts	(9,137)	(8,430)
Associated companies	306,933	143,524
Other	64,776	60,893
Accrued unbilled revenues	137,696	153,118
Total accounts receivable	719,790	603,413
Fuel inventory - at average cost	41,130	39,728
Materials and supplies - at average cost	309,433	299,881
Deferred nuclear refueling outage costs	52,723	65,711
Prepayments and other	41,147	34,035
TOTAL	1,726,509	1,078,675
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	1,390,587	1,390,587
Decommissioning trust funds	1,304,423	1,312,073
Non-utility property - at cost (less accumulated depreciation)	273,388	245,255
Storm Reserve Escrow Account	285,612	284,759
Other	14,407	18,999
TOTAL	3,268,417	3,251,673
PROPERTY, PLANT, AND EQUIPMENT
Electric	19,722,068	19,678,536
Natural gas	195,230	191,899
Construction work in progress	1,490,196	1,281,452
Nuclear fuel	275,750	337,402
TOTAL PROPERTY, PLANT, AND EQUIPMENT	21,683,244	21,489,289
Less - accumulated depreciation and amortization	8,597,382	8,703,047
PROPERTY, PLANT, AND EQUIPMENT - NET	13,085,862	12,786,242
Regulatory assets:
Other regulatory assets	1,117,263	1,145,842
Deferred fuel costs	168,122	168,122
Other	23,323	18,310
TOTAL	1,308,708	1,332,274
TOTAL ASSETS	19,389,496	18,448,864
CURRENT LIABILITIES
Currently maturing long-term debt	675,002	675,002
Short-term borrowings	62,922	43,540
Associated companies accounts payable	86,427	126,685
Other	375,783	404,374
Customer deposits	151,492	150,623
Taxes Payable, Current	0	18,157
Interest accrued	81,893	75,528
Deferred fuel costs	19,357	71,447
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	217,850	0
Other	63,165	79,037
TOTAL	1,733,891	1,644,393
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	2,144,037	2,050,371
Accumulated deferred investment tax credits	120,652	121,870
Regulatory liability for income taxes - net	506,092	725,368
Other regulatory liabilities	756,397	761,059
Decommissioning and asset retirement cost liabilities	1,240,833	1,140,461
Accumulated provisions	301,967	302,448
Pension and other postretirement liabilities	730,116	748,384
Long-term debt	6,263,437	5,469,069
Other	175,941	176,637
TOTAL	12,239,472	11,495,667
Common Shareholders' Equity:
Accumulated other comprehensive loss	(56,950)	(46,400)
Members' Equity	5,473,083	5,355,204
TOTAL	5,416,133	5,308,804
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	19,389,496	18,448,864
Entergy Mississippi [Member]
Cash and cash equivalents:
Cash	13	1,607
Temporary cash investments	290	4,489
Total cash and cash equivalents	303	6,096
Accounts receivable:
Customer	83,092	72,039
Allowance for doubtful accounts	(635)	(574)
Associated companies	39,490	45,081
Other	14,768	9,738
Accrued unbilled revenues	41,174	54,256
Total accounts receivable	177,889	180,540
Deferred fuel costs	18,627	32,444
Fuel inventory - at average cost	46,373	45,606
Materials and supplies - at average cost	42,957	42,571
Prepayments and other	8,120	7,041
TOTAL	294,269	314,298
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,588	4,592
Escrow accounts	32,061	31,969
TOTAL	36,649	36,561
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,725,645	4,660,297
Property under capital lease	0	125
Construction work in progress	146,168	149,367
TOTAL PROPERTY, PLANT, AND EQUIPMENT	4,871,813	4,809,789
Less - accumulated depreciation and amortization	1,711,157	1,681,306
PROPERTY, PLANT, AND EQUIPMENT - NET	3,160,656	3,128,483
Regulatory assets:
Other regulatory assets	393,323	397,909
Other	5,679	2,124
TOTAL	399,002	400,033
TOTAL ASSETS	3,890,576	3,879,375
CURRENT LIABILITIES
Associated companies accounts payable	117,633	55,689
Other	55,887	77,326
Customer deposits	83,574	83,654
Taxes Payable, Current	26,599	82,843
Interest accrued	17,353	22,901
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	162,140	0
Other	8,708	12,785
TOTAL	471,894	335,198
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	497,129	488,806
Accumulated deferred investment tax credits	8,827	8,867
Regulatory liability for income taxes - net	248,739	411,011
Decommissioning and asset retirement cost liabilities	9,348	9,219
Accumulated provisions	49,518	44,764
Pension and other postretirement liabilities	96,893	101,498
Long-term debt	1,270,399	1,270,122
Other	16,973	11,639
TOTAL	2,197,826	2,345,926
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	1,000,982	978,377
TOTAL	1,200,475	1,177,870
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	3,890,576	3,879,375
Entergy New Orleans [Member]
Cash and cash equivalents:
Cash	26	30
Temporary cash investments	1,334	32,711
Total cash and cash equivalents	1,360	32,741
Securitization recovery trust account	4,836	1,455
Accounts receivable:
Customer	51,744	51,006
Allowance for doubtful accounts	(3,072)	(3,057)
Associated companies	9,576	22,976
Other	10,051	6,471
Accrued unbilled revenues	14,066	20,638
Total accounts receivable	82,365	98,034
Deferred fuel costs	3,535	0
Fuel inventory - at average cost	939	1,890
Materials and supplies - at average cost	11,562	10,381
Prepaid Taxes	39,830	26,479
Prepayments and other	18,794	8,030
TOTAL	163,221	179,010
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	1,016	1,016
Storm Reserve Escrow Account	79,775	79,546
Other	0	2,373
TOTAL	80,791	82,935
PROPERTY, PLANT, AND EQUIPMENT
Electric	1,314,262	1,302,235
Natural gas	267,527	261,263
Construction work in progress	71,845	46,993
TOTAL PROPERTY, PLANT, AND EQUIPMENT	1,653,634	1,610,491
Less - accumulated depreciation and amortization	643,737	631,178
PROPERTY, PLANT, AND EQUIPMENT - NET	1,009,897	979,313
Regulatory assets:
Other regulatory assets	244,207	251,433
Deferred fuel costs	4,080	4,080
Other	1,843	1,065
TOTAL	250,130	256,578
TOTAL ASSETS	1,504,039	1,497,836
CURRENT LIABILITIES
Current Payable Due Associated Company	2,077	2,077
Associated companies accounts payable	43,119	47,472
Other	29,267	29,777
Customer deposits	28,727	28,442
Interest accrued	5,406	5,487
Deferred fuel costs	0	7,774
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	27,857	0
Other	4,564	7,351
TOTAL	141,017	128,380
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	302,461	283,302
Accumulated deferred investment tax credits	2,296	2,323
Regulatory liability for income taxes - net	90,359	119,259
Decommissioning and asset retirement cost liabilities	3,128	3,076
Accumulated provisions	85,279	85,083
Pension and other postretirement liabilities	17,061	20,755
Long-term debt	418,572	418,447
Long-Term Payable Due Associated Company	16,346	16,346
Other	7,340	5,317
TOTAL	942,842	953,908
Common Shareholders' Equity:
Common stock	420,180	415,548
TOTAL	420,180	415,548
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	1,504,039	1,497,836
Entergy Texas [Member]
Cash and cash equivalents:
Cash	26	32
Temporary cash investments	38,950	115,481
Total cash and cash equivalents	38,976	115,513
Securitization recovery trust account	29,698	37,683
Accounts receivable:
Customer	63,979	74,382
Allowance for doubtful accounts	(422)	(463)
Associated companies	68,569	90,629
Other	7,450	9,831
Accrued unbilled revenues	43,982	50,682
Total accounts receivable	183,558	225,061
Fuel inventory - at average cost	42,865	42,731
Materials and supplies - at average cost	39,294	38,605
Prepayments and other	13,502	19,710
TOTAL	347,893	479,303
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	481	457
Non-utility property - at cost (less accumulated depreciation)	376	376
Other	19,454	19,235
TOTAL	20,311	20,068
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,614,489	4,569,295
Construction work in progress	122,764	102,088
TOTAL PROPERTY, PLANT, AND EQUIPMENT	4,737,253	4,671,383
Less - accumulated depreciation and amortization	1,603,585	1,579,387
PROPERTY, PLANT, AND EQUIPMENT - NET	3,133,668	3,091,996
Regulatory assets:
Other regulatory assets	640,901	661,398
Other	28,731	26,973
TOTAL	669,632	688,371
TOTAL ASSETS	4,171,504	4,279,738
CURRENT LIABILITIES
Currently maturing long-term debt	500,000	0
Associated companies accounts payable	51,454	59,347
Other	87,369	126,095
Customer deposits	41,395	40,925
Taxes Payable, Current	49,640	45,659
Interest accrued	19,981	25,556
Deferred fuel costs	38,675	67,301
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	41,325	0
Other	6,926	8,132
TOTAL	836,765	373,015
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	522,688	544,642
Accumulated deferred investment tax credits	11,790	11,983
Regulatory liability for income taxes - net	372,230	412,620
Other regulatory liabilities	11,060	6,850
Decommissioning and asset retirement cost liabilities	6,930	6,835
Accumulated provisions	9,907	10,115
Pension and other postretirement liabilities	11,008	17,853
Long-term debt	1,062,555	1,587,150
Other	49,054	48,508
TOTAL	2,057,222	2,646,556
Common Shareholders' Equity:
Common stock	49,452	49,452
Paid-in capital	596,994	596,994
Retained earnings	631,071	613,721
TOTAL	1,277,517	1,260,167
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	4,171,504	4,279,738
System Energy [Member]
Cash and cash equivalents:
Cash	47	78
Temporary cash investments	278,652	287,109
Total cash and cash equivalents	278,699	287,187
Accounts receivable:
Associated companies	142,321	170,149
Other	6,940	6,526
Total accounts receivable	149,261	176,675
Materials and supplies - at average cost	89,431	88,424
Deferred nuclear refueling outage costs	9,668	7,908
Prepayments and other	5,596	2,489
TOTAL	532,655	562,683
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	896,219	905,686
TOTAL	896,219	905,686
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,331,713	4,327,849
Property under capital lease	588,281	588,281
Construction work in progress	100,467	69,937
Nuclear fuel	248,372	207,513
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,268,833	5,193,580
Less - accumulated depreciation and amortization	3,203,002	3,175,018
PROPERTY, PLANT, AND EQUIPMENT - NET	2,065,831	2,018,562
Regulatory assets:
Other regulatory assets	446,287	444,327
Other	11,363	7,629
TOTAL	457,650	451,956
TOTAL ASSETS	3,952,355	3,938,887
CURRENT LIABILITIES
Currently maturing long-term debt	85,005	85,004
Short-term borrowings	43,170	17,830
Associated companies accounts payable	6,189	16,878
Other	65,448	62,868
Taxes Payable, Current	31,551	46,584
Interest accrued	14,125	13,389
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	76,442	0
Other	2,437	2,434
TOTAL	324,367	244,987
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	785,726	776,420
Accumulated deferred investment tax credits	39,087	39,406
Regulatory liability for income taxes - net	167,518	246,122
Other regulatory liabilities	439,165	455,991
Decommissioning and asset retirement cost liabilities	870,120	861,664
Pension and other postretirement liabilities	118,337	121,874
Long-term debt	516,577	466,484
Other	21,581	15,130
TOTAL	2,958,111	2,983,091
Common Shareholders' Equity:
Common stock	601,850	658,350
Retained earnings	68,027	52,459
TOTAL	669,877	710,809
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$ 3,952,355	$ 3,938,887

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Securitization property	$ 455,148	$ 485,031
Securitization bonds	$ 520,253	$ 544,921
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	500,000,000	500,000,000
Common stock, shares issued	254,752,788	254,752,788
Treasury stock, shares	73,953,521	74,235,135
Entergy Arkansas [Member]
Securitization property	$ 24,682	$ 28,583
Securitization bonds	$ 34,739	$ 34,662
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	325,000,000	325,000,000
Common stock, shares issued	46,980,196	46,980,196
Common stock, shares outstanding	46,980,196	46,980,196
Entergy Louisiana [Member]
Securitization property	$ 66,296	$ 71,367
Securitization bonds	$ 77,801	$ 77,736
Entergy Mississippi [Member]
Common stock, shares authorized	12,000,000	12,000,000
Common stock, shares issued	8,666,357	8,666,357
Common stock, shares outstanding	8,666,357	8,666,357
Entergy New Orleans [Member]
Securitization property	$ 69,199	$ 72,095
Securitization bonds	74,480	74,419
Entergy Texas [Member]
Securitization property	295,062	313,123
Securitization bonds	$ 333,233	$ 358,104
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares issued	46,525,000	46,525,000
Common stock, shares outstanding	46,525,000	46,525,000
System Energy [Member]
Common stock, shares authorized	1,000,000	1,000,000
Common stock, shares issued	789,350	789,350
Common stock, shares outstanding	789,350	789,350

Consolidated Statements Of Chan

Consolidated Statements Of Changes In Equity - USD ($) $ in Thousands	Total		Subsidiaries Preferred Stock [Member]		Paid In Capital [Member]	Retained Earnings [Member]		Accumulated Other Comprehensive Income [Member]	Common Stock [Member]	Treasury Stock [Member]	Entergy Arkansas [Member]	Entergy Arkansas [Member]Paid In Capital [Member]	Entergy Arkansas [Member]Retained Earnings [Member]	Entergy Arkansas [Member]Common Stock [Member]	Entergy Louisiana [Member]	Entergy Louisiana [Member]Member's Equity [Member]	Entergy Louisiana [Member]Accumulated Other Comprehensive Income [Member]	Entergy Mississippi [Member]	Entergy Mississippi [Member]Capital Stock Expense and Other [Member]	Entergy Mississippi [Member]Retained Earnings [Member]	Entergy Mississippi [Member]Common Stock [Member]	Entergy New Orleans [Member]	Entergy Texas [Member]	Entergy Texas [Member]Paid In Capital [Member]	Entergy Texas [Member]Retained Earnings [Member]	Entergy Texas [Member]Common Stock [Member]	System Energy [Member]	System Energy [Member]Retained Earnings [Member]	System Energy [Member]Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 8,081,809		$ 0		$ 5,417,245	$ 8,195,571		$ (34,971)	$ 2,548	$ (5,498,584)	$ 2,253,317	$ 790,243	$ 1,462,604	$ 470	$ 5,081,809	$ 5,130,251	$ (48,442)	$ 1,094,791	$ 167	$ 895,298	$ 199,326	$ 426,946	$ 1,068,994	$ 481,994	$ 537,548	$ 49,452	$ 738,823	$ 59,473	$ 679,350
Consolidated net income	86,051	[1]	3,446	[1]	0	82,605	[1]	0	0	0	14,304	0	14,304	0	94,378	94,378	0	17,158	0	17,158	0	10,978	10,854	0	10,854	0	20,347	20,347	0
Other comprehensive income (loss)	45,931		0		0	0		45,931	0	0					(370)	0	(370)
Common stock issuances related to stock plans	2,917		0		(19,166)	0		0	0	22,083
Common stock	(156,073)		0		0	(156,073)		0	0	0					(42,125)	(42,125)	0					(12,200)					0
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable	3,446	[1]	3,446	[1]	0	0		0	0	0	357	0	357	0				238	0	238	0	241
Other															(4)	(4)	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	8,057,189		0		5,398,079	8,122,103		10,960	2,548	(5,476,501)	2,267,264	790,243	1,476,551	470	5,133,688	5,182,500	(48,812)	1,111,711	167	912,218	199,326	425,483	1,079,848	481,994	548,402	49,452	759,170	79,820	679,350
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	7,992,515		0		5,433,433	7,977,702		(23,531)	2,548	(5,397,637)	2,376,754	790,264	1,586,020	470	5,308,804	5,355,204	(46,400)	1,177,870	167	978,377	199,326	415,548	1,260,167	596,994	613,721	49,452	710,809	52,459	658,350
Consolidated net income	136,200	[1]	3,439	[1]	0	132,761	[1]	0	0	0	36,255	0	36,255	0	111,593	111,593	0	22,843	0	22,843	0	10,882	17,350	0	17,350	0	22,308	22,308	0
Dividends, Common Stock, Cash																												6,740	56,500
Other comprehensive income (loss)	79,145		0		0	0		79,145	0	0					(501)	0	(501)
Common stock issuances related to stock plans	4,307		0		(16,170)	0		0	0	20,477
Common stock	(160,887)		0		0	(160,887)		0	0	0					0							(6,250)					(63,240)
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable	3,439	[1]	3,439	[1]	0	0		0	0	0	357	0	357	0				238	0	238	0	0
Other															24	24	0
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect	(16,538)	[1]	0	[1]	0	(32,043)		15,505	0	0					(3,787)	6,262	(10,049)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 7,974,943		$ 0		$ 5,417,263	$ 8,493,790		$ (561,498)	$ 2,548	$ (5,377,160)	$ 2,412,652	$ 790,264	$ 1,621,918	$ 470	$ 5,416,133	$ 5,473,083	$ (56,950)	$ 1,200,475	$ 167	$ 1,000,982	$ 199,326	$ 420,180	$ 1,277,517	$ 596,994	$ 631,071	$ 49,452	$ 669,877	$ 68,027	$ 601,850
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Consolidated Statements Of Cha7

Consolidated Statements Of Changes In Equity (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Statement of Stockholders' Equity [Abstract]
Preferred dividends on subsidiaries' preferred stock	$ 3.4	$ 3.4

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2018	Mar. 31, 2017
Net income	[1]	$ 136,200	$ 86,051
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss)		95,427	(528)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax		16,574	8,632
Net unrealized investment gains		(32,856)	37,827
Other comprehensive income (loss)		79,145	45,931
Total comprehensive income		215,345	131,982
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders		3,439	3,446
Comprehensive Income Attributable to Entergy Corporation		211,906	128,536
Entergy Louisiana [Member]
Net income		111,593	94,378
Other comprehensive income (loss)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax		(501)	(370)
Other comprehensive income (loss)		(501)	(370)
Total comprehensive income		$ 111,092	$ 94,008
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Consolidated Statements Of Com9

Consolidated Statements Of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Tax	$ 25,349	$ (359)
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	4,568	6,377
Other Comprehensive Income (Loss), Available-for-sale Securities, Tax	5,375	39,294
Entergy Louisiana [Member]
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	$ (176)	$ (232)

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2018
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Planned Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s planned shutdown of Pilgrim on May 31, 2019. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Entergy Arkansas [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Planned Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s planned shutdown of Pilgrim on May 31, 2019. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Entergy Louisiana [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Planned Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s planned shutdown of Pilgrim on May 31, 2019. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Entergy Mississippi [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Planned Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s planned shutdown of Pilgrim on May 31, 2019. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Entergy New Orleans [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Planned Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s planned shutdown of Pilgrim on May 31, 2019. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Entergy Texas [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Planned Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s planned shutdown of Pilgrim on May 31, 2019. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
System Energy [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Planned Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s planned shutdown of Pilgrim on May 31, 2019. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.

Rate And Regulatory Matters

Rate And Regulatory Matters	3 Months Ended
	Mar. 31, 2018
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements in the Form 10-K for discussion of the effects of the enactment in December 2017 of the Tax Cuts and Jobs Act (the Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. After assessing the activity described in more detail below regarding the proposals the Registrant Subsidiaries have made to their regulators for the return of unprotected excess accumulated deferred income taxes to customers, in the first quarter 2018, Entergy and each of the Registrant Subsidiaries reclassified from the regulatory liability for income taxes to current liabilities the portion of their unprotected excess accumulated deferred income taxes that they expect to return to customers over the next twelve months. Entergy Arkansas See the Form 10-K for a discussion of the activity of the APSC and Entergy Arkansas after enactment of the Tax Act in December 2017. The APSC granted Entergy Arkansas’s request for clarification regarding the APSC’s order issued after enactment of the Tax Act. The APSC states that its order was not a final determination and that the APSC has made no decision at this time on the appropriate final accounting or ratemaking treatment of the amounts in question. Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff docket in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits associated with the Tax Act. For the residential customer class, the unprotected excess accumulated deferred income taxes will be returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, the unprotected excess accumulated deferred income taxes will be returned to customers over a 9-month period from April 2018 through December 2018. A true-up provision also was included, with any over- or under-returned unprotected excess accumulated deferred income taxes to be credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. Entergy Louisiana See the Form 10-K for a discussion of the activity of the LPSC and Entergy Louisiana after enactment of the Tax Act in December 2017. At the March 2018 LPSC Business and Executive Session, the LPSC staff provided a report on the tax-related rulemaking and invited additional interventions and comments before a proposed rule is issued. The LPSC staff commented that the proposed rule would likely set forth a generic mechanism that can be used by utilities to reflect the effects of the Tax Act in rates and a process by which utilities can propose utility specific treatment, if desired. See the “Formula Rate Plan Extension Request” discussion below. In the formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana will return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the parties agreed that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana would establish a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month until new base rates under the formula rate plan are established, and this regulatory liability will be returned to customers over the next formula rate plan rate-effective period. Entergy Louisiana recorded a $27 million regulatory liability in the first quarter 2018 pursuant to this provision of the settlement. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and analysis thereof as part of the formula rate plan review proceeding for the upcoming 2017 test year filing. Entergy Mississippi As discussed in the Form 10-K, after enactment of the Tax Act the MPSC ordered utilities, including Entergy Mississippi, that operate under a formula rate plan to file a description by February 26, 2018, of how the Tax Act will be reflected in the formula rate plan under which the utility operates. Entergy Mississippi's plan, as filed with the MPSC on February 26, 2018, included a request to reflect the changes related to the Tax Act in the 2018 formula rate plan filing. Entergy Mississippi filed its 2018 formula rate plan on March 15, 2018 and included a proposal to return all of its unprotected excess accumulated deferred income taxes to customers through rates or in exchange for other assets, or a combination of both, by the end of 2018. Also, in March 2018 the MPSC issued a subsequent order in its generic tax reform docket ordering utilities, including Entergy Mississippi, to explain the implementation of the utilities tax adjustment clause, or, in the alternative, why the tax adjustment clause is inapplicable; submit an analysis of the ratemaking effects of the Tax Act on current and future revenue requirements for rate schedules that include a gross-up for federal taxes; and make appropriate accounting entries to recognize the removal of excess deferred taxes from the balance of the utility’s accumulated deferred income tax account, or, in the alternative, explain why recording such entries is not appropriate. In April 2018, Entergy Mississippi filed its response to the MPSC stating that the tax adjustment clauses in its base rates are properly implemented through its formula rate plan. Entergy Mississippi also provided analysis of the ratemaking effects of the Tax Act. Entergy New Orleans As discussed in the Form 10-K, after enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. In March 2018, Entergy New Orleans filed its response to that resolution stating that the Tax Act reduced income tax expense from what is presently reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy has submitted filings of this type to the FERC. System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposes to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2018, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01547 per kWh to $0.01882 per kWh. The Arkansas Attorney General filed a response to Entergy Arkansas’s annual redetermination filing requesting that the APSC suspend the proposed tariff to investigate the amount of the redetermination or, alternatively, to allow recovery subject to refund. Among the reasons the Arkansas Attorney General cited for suspension were questions pertaining to how Entergy Arkansas forecasted sales and potential implications of the Tax Act. Entergy Arkansas replied to the Arkansas Attorney General’s filing and stated that, to the extent there are questions pertaining to its load forecasting or the operation of the energy cost recovery rider, those issues exceed the scope of the instant rate redetermination. Entergy Arkansas also stated that potential effects of the Tax Act are appropriately considered in the APSC’s separate proceeding looking at potential implications of the new tax law. The APSC general staff filed a reply to the Arkansas Attorney General’s filing and agreed that Entergy Arkansas’s filing complied with the terms of the energy cost recovery rider. In April 2018 the APSC issued an order declining to suspend Entergy Arkansas’s energy cost recovery rider rate and declining to require further investigation of the issues suggested by the Attorney General in the proceeding at this time. The redetermined rate became effective with the first billing cycle of April 2018. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in an open PUCT proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. The pending appeals did not stay the PUCT’s decision, and Entergy Texas refunded to customers the $10.9 million over a four-month period beginning with the first billing cycle of July 2016. The federal appeal of the PUCT’s January 2016 decision was heard in December 2016, and the Federal District Court granted Entergy Texas’s requested relief. In January 2017 the PUCT and an intervenor filed petitions for appeal to the U.S. Court of Appeals for the Fifth Circuit of the Federal District Court ruling. Oral argument was held before the U.S. Court of Appeals for the Fifth Circuit in February 2018. In April 2018 the U.S. Court of Appeals for the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. Entergy Texas is considering its legal options. The State District Court appeal of the PUCT’s January 2016 decision remains pending. In December 2017, Entergy Texas filed an application for a fuel refund of approximately $30.5 million for the months of May 2017 through October 2017. Also in December 2017, the PUCT’s ALJ approved the refund on an interim basis. For most customers, the refunds flowed through bills beginning January 2018 and continued through March 2018. The fuel refund was approved by the PUCT in March 2018. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC (Entergy Arkansas) Internal Restructuring As discussed in the Form 10-K, in November 2017, Entergy Arkansas filed an application with the APSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Arkansas to a new entity, which would ultimately be owned by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval by the APSC, the FERC, and the NRC. Entergy Arkansas also filed a notice with the Missouri Public Service Commission in December 2017 out of an abundance of caution, although Entergy Arkansas does not serve any retail customers in Missouri. In April 2018 the Missouri Public Service Commission approved Entergy Arkansas’s filing. If the appropriate approvals are obtained, Entergy Arkansas expects the restructuring will be consummated on or before December 1, 2018. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric Formula Rate Plan Extension Request In August 2017, Entergy Louisiana filed a request with the LPSC seeking to extend its formula rate plan for three years (2017-2019) with limited modifications of its terms. Those modifications include: a one-time resetting of base rates to the midpoint of the band at Entergy Louisiana’s authorized return on equity of 9.95% for the 2017 test year; narrowing of the formula rate plan bandwidth from a total of 160 basis points to 80 basis points; and a forward-looking mechanism that would allow Entergy Louisiana to recover certain transmission-related costs contemporaneously with when those projects begin delivering benefits to customers. Several parties intervened in the proceeding and all parties participated in settlement discussions. In April 2018 the LPSC approved an unopposed joint motion filed by Entergy Louisiana and the LPSC staff that settles the matter. The settlement extends the formula rate plan for three years, providing for rates through at least August 2021. In addition to retaining the major features of the traditional formula rate plan, substantive features of the extended formula rate plan include: • a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation; • a 9.8% target earned return on common equity for the 2018 and 2019 test years; • narrowing of the common equity bandwidth to plus or minus 60 basis points around the earned return on common equity; • a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity); • a framework for the flow back of certain tax benefits created by the Tax Act to customers, as described in “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above; and • a transmission recovery mechanism providing for the opportunity to recover certain transmission related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism. Union Power Station and Deactivation or Retirement Decisions for Entergy Louisiana Plants As discussed in the Form 10-K, as a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three-year term permitted by MISO. In March 2018 the LPSC adopted the ALJ’s recommended order finding that Entergy Louisiana did not demonstrate that its decision to permanently surrender transmission rights for the mothballed (not retired) Willow Glen 2 and 4 units was reasonable and that Entergy Louisiana should hold customers harmless from increased transmission expenses should those units be reactivated. Because no party or the LPSC suggested that Willow Glen 2 and 4 should be reactivated and because the cost to return those units to service far exceeds the revenue the units were expected to generate in MISO, Entergy Louisiana retired Willow Glen 2 and 4 in March 2018. Retail Rates - Gas 2017 Rate Stabilization Plan Filing In January 2018, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. The filing of the evaluation report for the test year 2017 reflected an earned return on common equity of 9.06% . This earned return is below the earnings sharing band of the rate stabilization plan and results in a rate increase of $0.1 million . Due to the enactment of the Tax Act in late-December 2017, Entergy Louisiana did not have adequate time to reflect the effects of this tax legislation in the rate stabilization plan. In April 2018 Entergy Louisiana filed a supplemental evaluation report for the test year ended September 2017, reflecting the effects of the Tax Act, including a proposal to use the unprotected excess accumulated deferred income taxes to offset storm restoration deferred operation and maintenance costs incurred by Entergy Louisiana in connection with the August 2016 flooding disaster in its gas service area. The supplemental filing reflects an earned return on common equity of 10.79% . If the as-filed rates from the supplemental filing are accepted by the LPSC, customers will receive a cost reduction of approximately $0.7 million effective with bills rendered on and after the first billing cycle of May 2018, as well as a $0.2 million prospective reduction in the gas infrastructure rider effective with bills rendered on and after the first billing cycle of July 2018. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2018, Entergy Mississippi submitted its formula rate plan 2018 test year filing and 2017 look-back filing showing Entergy Mississippi’s earned return for the historical 2017 calendar year and projected earned return for the 2018 calendar year, in large part as a result of the lower federal corporate income tax rate effective in 2018, to be within the formula rate plan bandwidth, resulting in no change in rates. The filing is currently subject to MPSC review. See “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above for additional discussion regarding the proposed treatment of the effects of the lower federal corporate income tax rate. Internal Restructuring In March 2018, Entergy Mississippi filed an application with the MPSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Mississippi to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval by the MPSC, the FERC, and the NRC. If the MPSC approves the restructuring by August 2018 and the restructuring closes on or before December 1, 2018, Entergy Mississippi proposed in its application to credit retail customers $27 million over six years, beginning in 2019. If the MPSC, the FERC, and the NRC approvals are obtained, Entergy Mississippi expects the restructuring will be consummated on or before December 1, 2018. It is currently contemplated that Entergy Mississippi would undertake a multi-step restructuring, which would include the following: • Entergy Mississippi would redeem its outstanding preferred stock, at the aggregate redemption price of approximately $21.2 million , including call premiums, plus accumulated and unpaid dividends, if any. • Entergy Mississippi would convert from a Mississippi corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy Mississippi will allocate substantially all of its assets to a new subsidiary, Entergy Mississippi Power and Light, LLC, a Texas limited liability company (Entergy Mississippi Power and Light), and Entergy Mississippi Power and Light will assume substantially all of the liabilities of Entergy Mississippi, in a transaction regarded as a merger under the TXBOC. Entergy Mississippi will remain in existence and hold the membership interests in Entergy Mississippi Power and Light. • Entergy Mississippi will contribute the membership interests in Entergy Mississippi Power and Light to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy Mississippi Power and Light will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC. • Entergy Mississippi will change its name to Entergy Utility Enterprises, Inc., and Entergy Mississippi Power and Light will then change its name to Entergy Mississippi, LLC. Upon the completion of the restructuring, Entergy Mississippi, LLC will hold substantially all of the assets, and will have assumed substantially all of the liabilities, of Entergy Mississippi. Entergy Mississippi may modify or supplement the steps to be taken to effectuate the restructuring. Advanced Metering Infrastructure (AMI) Filings Entergy New Orleans As discussed in the Form 10-K, in February 2018 the City Council approved Entergy New Orleans’s application seeking a finding that Entergy New Orleans’s deployment of advanced electric and gas metering infrastructure is in the public interest. Deployment of the information technology infrastructure began in 2017 and deployment of the communications network is expected to begin later in 2018. In April 2018 the City Council adopted a resolution directing Entergy New Orleans to explore the options for accelerating the deployment of AMI. Entergy New Orleans is required to report its findings to the City Council by June 2018. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, in August 2017 the D.C. Circuit issued a decision denying the LPSC’s appeal of the FERC’s October 2011 and February 2014 orders, but also granting the request by all parties to the appeal for remand and agency reconsideration on the issue of whether the operating companies should be required to issue refunds for the 20-month period from September 2001 to May 2003. The matter was remanded back to the FERC and, in March 2018, the LPSC filed at the FERC its initial brief addressing the issue that the D.C. Circuit remanded back to the FERC in August 2017. In its brief, the LPSC argued that the FERC should require the Utility operating companies to issue refunds for the 20-month refund period from September 2001 to May 2003. Rough Production Cost Equalization Rates Consolidated 2011, 2012, 2013, and 2014 Rate Filing Proceedings As discussed in the Form 10-K, in December 2014 the FERC consolidated the 2011, 2012, 2013, and 2014 rate filings for settlement and hearing procedures. In May 2015, Entergy filed direct testimony in the consolidated rate filings and the LPSC filed direct testimony concerning its complaint proceeding that is consolidated with the rate filings, challenging certain components of the pending bandwidth calculations for prior years. Hearings occurred in November 2015, and the ALJ issued an initial decision in July 2016. In the initial decision, the ALJ generally agreed with Entergy’s bandwidth calculations with one exception on the accounting related to the Waterford 3 sale/leaseback. In March 2018 the FERC issued an order affirming the initial decision. In April 2018 the LPSC requested rehearing of the FERC’s March 2018 order affirming the ALJ’s initial decision. Based on the March 2018 FERC order, the following preliminary estimated payments/receipts were recorded in March 2018 among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $6 Entergy New Orleans $2 Entergy Texas ($8) Entergy Services expects to file in May 2018 the bandwidth true-up payments and receipts for the 2011-2014 rate filings. Interruptible Load Proceedings See the Form 10-K for a discussion of the interruptible load proceedings. As discussed in the Form 10-K, the LPSC appealed the April and September 2016 orders to the D.C. Circuit. In March 2018 the D.C. Circuit issued an order denying the LPSC’s appeal and affirming the FERC’s decision that it would be inequitable to award refunds in the proceeding. In April 2018 the LPSC sought rehearing en banc of the D.C. Circuit’s order denying the LPSC’s appeal. Complaint Against System Energy As discussed in the Form 10-K, in January 2017 the APSC and the MPSC filed a complaint requesting that the FERC establish proceedings to investigate System Energy’s return on equity under the Unit Power Sales Agreement, establish a refund effective date, and establish a new and lower return on equity. In September 2017 the FERC established a refund effective date of January 23, 2017, consolidated the return on equity complaint with the proceeding described in “ Unit Power Sales Agreement ” in the Form 10-K, and directed the parties to engage in settlement proceedings before an ALJ. Settlement discussions are ongoing. The refund effective date in connection with the APSC/MPSC complaint expired on April 23, 2018. In April 2018 the LPSC filed a complaint with the FERC against System Energy seeking an additional fifteen-month refund period. The LPSC complaint requests similar relief from the FERC with respect to System Energy’s return on equity and also requests the FERC to investigate System Energy’s capital structure and application of System Energy’s allowed depreciation rates to plant additions associated with the Grand Gulf sale/leaseback transactions. System Energy expects to answer the LPSC complaint in May 2018.
Entergy Arkansas [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements in the Form 10-K for discussion of the effects of the enactment in December 2017 of the Tax Cuts and Jobs Act (the Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. After assessing the activity described in more detail below regarding the proposals the Registrant Subsidiaries have made to their regulators for the return of unprotected excess accumulated deferred income taxes to customers, in the first quarter 2018, Entergy and each of the Registrant Subsidiaries reclassified from the regulatory liability for income taxes to current liabilities the portion of their unprotected excess accumulated deferred income taxes that they expect to return to customers over the next twelve months. Entergy Arkansas See the Form 10-K for a discussion of the activity of the APSC and Entergy Arkansas after enactment of the Tax Act in December 2017. The APSC granted Entergy Arkansas’s request for clarification regarding the APSC’s order issued after enactment of the Tax Act. The APSC states that its order was not a final determination and that the APSC has made no decision at this time on the appropriate final accounting or ratemaking treatment of the amounts in question. Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff docket in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits associated with the Tax Act. For the residential customer class, the unprotected excess accumulated deferred income taxes will be returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, the unprotected excess accumulated deferred income taxes will be returned to customers over a 9-month period from April 2018 through December 2018. A true-up provision also was included, with any over- or under-returned unprotected excess accumulated deferred income taxes to be credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. Entergy Louisiana See the Form 10-K for a discussion of the activity of the LPSC and Entergy Louisiana after enactment of the Tax Act in December 2017. At the March 2018 LPSC Business and Executive Session, the LPSC staff provided a report on the tax-related rulemaking and invited additional interventions and comments before a proposed rule is issued. The LPSC staff commented that the proposed rule would likely set forth a generic mechanism that can be used by utilities to reflect the effects of the Tax Act in rates and a process by which utilities can propose utility specific treatment, if desired. See the “Formula Rate Plan Extension Request” discussion below. In the formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana will return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the parties agreed that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana would establish a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month until new base rates under the formula rate plan are established, and this regulatory liability will be returned to customers over the next formula rate plan rate-effective period. Entergy Louisiana recorded a $27 million regulatory liability in the first quarter 2018 pursuant to this provision of the settlement. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and analysis thereof as part of the formula rate plan review proceeding for the upcoming 2017 test year filing. Entergy Mississippi As discussed in the Form 10-K, after enactment of the Tax Act the MPSC ordered utilities, including Entergy Mississippi, that operate under a formula rate plan to file a description by February 26, 2018, of how the Tax Act will be reflected in the formula rate plan under which the utility operates. Entergy Mississippi's plan, as filed with the MPSC on February 26, 2018, included a request to reflect the changes related to the Tax Act in the 2018 formula rate plan filing. Entergy Mississippi filed its 2018 formula rate plan on March 15, 2018 and included a proposal to return all of its unprotected excess accumulated deferred income taxes to customers through rates or in exchange for other assets, or a combination of both, by the end of 2018. Also, in March 2018 the MPSC issued a subsequent order in its generic tax reform docket ordering utilities, including Entergy Mississippi, to explain the implementation of the utilities tax adjustment clause, or, in the alternative, why the tax adjustment clause is inapplicable; submit an analysis of the ratemaking effects of the Tax Act on current and future revenue requirements for rate schedules that include a gross-up for federal taxes; and make appropriate accounting entries to recognize the removal of excess deferred taxes from the balance of the utility’s accumulated deferred income tax account, or, in the alternative, explain why recording such entries is not appropriate. In April 2018, Entergy Mississippi filed its response to the MPSC stating that the tax adjustment clauses in its base rates are properly implemented through its formula rate plan. Entergy Mississippi also provided analysis of the ratemaking effects of the Tax Act. Entergy New Orleans As discussed in the Form 10-K, after enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. In March 2018, Entergy New Orleans filed its response to that resolution stating that the Tax Act reduced income tax expense from what is presently reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy has submitted filings of this type to the FERC. System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposes to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2018, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01547 per kWh to $0.01882 per kWh. The Arkansas Attorney General filed a response to Entergy Arkansas’s annual redetermination filing requesting that the APSC suspend the proposed tariff to investigate the amount of the redetermination or, alternatively, to allow recovery subject to refund. Among the reasons the Arkansas Attorney General cited for suspension were questions pertaining to how Entergy Arkansas forecasted sales and potential implications of the Tax Act. Entergy Arkansas replied to the Arkansas Attorney General’s filing and stated that, to the extent there are questions pertaining to its load forecasting or the operation of the energy cost recovery rider, those issues exceed the scope of the instant rate redetermination. Entergy Arkansas also stated that potential effects of the Tax Act are appropriately considered in the APSC’s separate proceeding looking at potential implications of the new tax law. The APSC general staff filed a reply to the Arkansas Attorney General’s filing and agreed that Entergy Arkansas’s filing complied with the terms of the energy cost recovery rider. In April 2018 the APSC issued an order declining to suspend Entergy Arkansas’s energy cost recovery rider rate and declining to require further investigation of the issues suggested by the Attorney General in the proceeding at this time. The redetermined rate became effective with the first billing cycle of April 2018. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in an open PUCT proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. The pending appeals did not stay the PUCT’s decision, and Entergy Texas refunded to customers the $10.9 million over a four-month period beginning with the first billing cycle of July 2016. The federal appeal of the PUCT’s January 2016 decision was heard in December 2016, and the Federal District Court granted Entergy Texas’s requested relief. In January 2017 the PUCT and an intervenor filed petitions for appeal to the U.S. Court of Appeals for the Fifth Circuit of the Federal District Court ruling. Oral argument was held before the U.S. Court of Appeals for the Fifth Circuit in February 2018. In April 2018 the U.S. Court of Appeals for the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. Entergy Texas is considering its legal options. The State District Court appeal of the PUCT’s January 2016 decision remains pending. In December 2017, Entergy Texas filed an application for a fuel refund of approximately $30.5 million for the months of May 2017 through October 2017. Also in December 2017, the PUCT’s ALJ approved the refund on an interim basis. For most customers, the refunds flowed through bills beginning January 2018 and continued through March 2018. The fuel refund was approved by the PUCT in March 2018. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC (Entergy Arkansas) Internal Restructuring As discussed in the Form 10-K, in November 2017, Entergy Arkansas filed an application with the APSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Arkansas to a new entity, which would ultimately be owned by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval by the APSC, the FERC, and the NRC. Entergy Arkansas also filed a notice with the Missouri Public Service Commission in December 2017 out of an abundance of caution, although Entergy Arkansas does not serve any retail customers in Missouri. In April 2018 the Missouri Public Service Commission approved Entergy Arkansas’s filing. If the appropriate approvals are obtained, Entergy Arkansas expects the restructuring will be consummated on or before December 1, 2018. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric Formula Rate Plan Extension Request In August 2017, Entergy Louisiana filed a request with the LPSC seeking to extend its formula rate plan for three years (2017-2019) with limited modifications of its terms. Those modifications include: a one-time resetting of base rates to the midpoint of the band at Entergy Louisiana’s authorized return on equity of 9.95% for the 2017 test year; narrowing of the formula rate plan bandwidth from a total of 160 basis points to 80 basis points; and a forward-looking mechanism that would allow Entergy Louisiana to recover certain transmission-related costs contemporaneously with when those projects begin delivering benefits to customers. Several parties intervened in the proceeding and all parties participated in settlement discussions. In April 2018 the LPSC approved an unopposed joint motion filed by Entergy Louisiana and the LPSC staff that settles the matter. The settlement extends the formula rate plan for three years, providing for rates through at least August 2021. In addition to retaining the major features of the traditional formula rate plan, substantive features of the extended formula rate plan include: • a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation; • a 9.8% target earned return on common equity for the 2018 and 2019 test years; • narrowing of the common equity bandwidth to plus or minus 60 basis points around the earned return on common equity; • a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity); • a framework for the flow back of certain tax benefits created by the Tax Act to customers, as described in “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above; and • a transmission recovery mechanism providing for the opportunity to recover certain transmission related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism. Union Power Station and Deactivation or Retirement Decisions for Entergy Louisiana Plants As discussed in the Form 10-K, as a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three-year term permitted by MISO. In March 2018 the LPSC adopted the ALJ’s recommended order finding that Entergy Louisiana did not demonstrate that its decision to permanently surrender transmission rights for the mothballed (not retired) Willow Glen 2 and 4 units was reasonable and that Entergy Louisiana should hold customers harmless from increased transmission expenses should those units be reactivated. Because no party or the LPSC suggested that Willow Glen 2 and 4 should be reactivated and because the cost to return those units to service far exceeds the revenue the units were expected to generate in MISO, Entergy Louisiana retired Willow Glen 2 and 4 in March 2018. Retail Rates - Gas 2017 Rate Stabilization Plan Filing In January 2018, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. The filing of the evaluation report for the test year 2017 reflected an earned return on common equity of 9.06% . This earned return is below the earnings sharing band of the rate stabilization plan and results in a rate increase of $0.1 million . Due to the enactment of the Tax Act in late-December 2017, Entergy Louisiana did not have adequate time to reflect the effects of this tax legislation in the rate stabilization plan. In April 2018 Entergy Louisiana filed a supplemental evaluation report for the test year ended September 2017, reflecting the effects of the Tax Act, including a proposal to use the unprotected excess accumulated deferred income taxes to offset storm restoration deferred operation and maintenance costs incurred by Entergy Louisiana in connection with the August 2016 flooding disaster in its gas service area. The supplemental filing reflects an earned return on common equity of 10.79% . If the as-filed rates from the supplemental filing are accepted by the LPSC, customers will receive a cost reduction of approximately $0.7 million effective with bills rendered on and after the first billing cycle of May 2018, as well as a $0.2 million prospective reduction in the gas infrastructure rider effective with bills rendered on and after the first billing cycle of July 2018. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2018, Entergy Mississippi submitted its formula rate plan 2018 test year filing and 2017 look-back filing showing Entergy Mississippi’s earned return for the historical 2017 calendar year and projected earned return for the 2018 calendar year, in large part as a result of the lower federal corporate income tax rate effective in 2018, to be within the formula rate plan bandwidth, resulting in no change in rates. The filing is currently subject to MPSC review. See “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above for additional discussion regarding the proposed treatment of the effects of the lower federal corporate income tax rate. Internal Restructuring In March 2018, Entergy Mississippi filed an application with the MPSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Mississippi to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval by the MPSC, the FERC, and the NRC. If the MPSC approves the restructuring by August 2018 and the restructuring closes on or before December 1, 2018, Entergy Mississippi proposed in its application to credit retail customers $27 million over six years, beginning in 2019. If the MPSC, the FERC, and the NRC approvals are obtained, Entergy Mississippi expects the restructuring will be consummated on or before December 1, 2018. It is currently contemplated that Entergy Mississippi would undertake a multi-step restructuring, which would include the following: • Entergy Mississippi would redeem its outstanding preferred stock, at the aggregate redemption price of approximately $21.2 million , including call premiums, plus accumulated and unpaid dividends, if any. • Entergy Mississippi would convert from a Mississippi corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy Mississippi will allocate substantially all of its assets to a new subsidiary, Entergy Mississippi Power and Light, LLC, a Texas limited liability company (Entergy Mississippi Power and Light), and Entergy Mississippi Power and Light will assume substantially all of the liabilities of Entergy Mississippi, in a transaction regarded as a merger under the TXBOC. Entergy Mississippi will remain in existence and hold the membership interests in Entergy Mississippi Power and Light. • Entergy Mississippi will contribute the membership interests in Entergy Mississippi Power and Light to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy Mississippi Power and Light will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC. • Entergy Mississippi will change its name to Entergy Utility Enterprises, Inc., and Entergy Mississippi Power and Light will then change its name to Entergy Mississippi, LLC. Upon the completion of the restructuring, Entergy Mississippi, LLC will hold substantially all of the assets, and will have assumed substantially all of the liabilities, of Entergy Mississippi. Entergy Mississippi may modify or supplement the steps to be taken to effectuate the restructuring. Advanced Metering Infrastructure (AMI) Filings Entergy New Orleans As discussed in the Form 10-K, in February 2018 the City Council approved Entergy New Orleans’s application seeking a finding that Entergy New Orleans’s deployment of advanced electric and gas metering infrastructure is in the public interest. Deployment of the information technology infrastructure began in 2017 and deployment of the communications network is expected to begin later in 2018. In April 2018 the City Council adopted a resolution directing Entergy New Orleans to explore the options for accelerating the deployment of AMI. Entergy New Orleans is required to report its findings to the City Council by June 2018. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, in August 2017 the D.C. Circuit issued a decision denying the LPSC’s appeal of the FERC’s October 2011 and February 2014 orders, but also granting the request by all parties to the appeal for remand and agency reconsideration on the issue of whether the operating companies should be required to issue refunds for the 20-month period from September 2001 to May 2003. The matter was remanded back to the FERC and, in March 2018, the LPSC filed at the FERC its initial brief addressing the issue that the D.C. Circuit remanded back to the FERC in August 2017. In its brief, the LPSC argued that the FERC should require the Utility operating companies to issue refunds for the 20-month refund period from September 2001 to May 2003. Rough Production Cost Equalization Rates Consolidated 2011, 2012, 2013, and 2014 Rate Filing Proceedings As discussed in the Form 10-K, in December 2014 the FERC consolidated the 2011, 2012, 2013, and 2014 rate filings for settlement and hearing procedures. In May 2015, Entergy filed direct testimony in the consolidated rate filings and the LPSC filed direct testimony concerning its complaint proceeding that is consolidated with the rate filings, challenging certain components of the pending bandwidth calculations for prior years. Hearings occurred in November 2015, and the ALJ issued an initial decision in July 2016. In the initial decision, the ALJ generally agreed with Entergy’s bandwidth calculations with one exception on the accounting related to the Waterford 3 sale/leaseback. In March 2018 the FERC issued an order affirming the initial decision. In April 2018 the LPSC requested rehearing of the FERC’s March 2018 order affirming the ALJ’s initial decision. Based on the March 2018 FERC order, the following preliminary estimated payments/receipts were recorded in March 2018 among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $6 Entergy New Orleans $2 Entergy Texas ($8) Entergy Services expects to file in May 2018 the bandwidth true-up payments and receipts for the 2011-2014 rate filings. Interruptible Load Proceedings See the Form 10-K for a discussion of the interruptible load proceedings. As discussed in the Form 10-K, the LPSC appealed the April and September 2016 orders to the D.C. Circuit. In March 2018 the D.C. Circuit issued an order denying the LPSC’s appeal and affirming the FERC’s decision that it would be inequitable to award refunds in the proceeding. In April 2018 the LPSC sought rehearing en banc of the D.C. Circuit’s order denying the LPSC’s appeal. Complaint Against System Energy As discussed in the Form 10-K, in January 2017 the APSC and the MPSC filed a complaint requesting that the FERC establish proceedings to investigate System Energy’s return on equity under the Unit Power Sales Agreement, establish a refund effective date, and establish a new and lower return on equity. In September 2017 the FERC established a refund effective date of January 23, 2017, consolidated the return on equity complaint with the proceeding described in “ Unit Power Sales Agreement ” in the Form 10-K, and directed the parties to engage in settlement proceedings before an ALJ. Settlement discussions are ongoing. The refund effective date in connection with the APSC/MPSC complaint expired on April 23, 2018. In April 2018 the LPSC filed a complaint with the FERC against System Energy seeking an additional fifteen-month refund period. The LPSC complaint requests similar relief from the FERC with respect to System Energy’s return on equity and also requests the FERC to investigate System Energy’s capital structure and application of System Energy’s allowed depreciation rates to plant additions associated with the Grand Gulf sale/leaseback transactions. System Energy expects to answer the LPSC complaint in May 2018.
Entergy Louisiana [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements in the Form 10-K for discussion of the effects of the enactment in December 2017 of the Tax Cuts and Jobs Act (the Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. After assessing the activity described in more detail below regarding the proposals the Registrant Subsidiaries have made to their regulators for the return of unprotected excess accumulated deferred income taxes to customers, in the first quarter 2018, Entergy and each of the Registrant Subsidiaries reclassified from the regulatory liability for income taxes to current liabilities the portion of their unprotected excess accumulated deferred income taxes that they expect to return to customers over the next twelve months. Entergy Arkansas See the Form 10-K for a discussion of the activity of the APSC and Entergy Arkansas after enactment of the Tax Act in December 2017. The APSC granted Entergy Arkansas’s request for clarification regarding the APSC’s order issued after enactment of the Tax Act. The APSC states that its order was not a final determination and that the APSC has made no decision at this time on the appropriate final accounting or ratemaking treatment of the amounts in question. Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff docket in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits associated with the Tax Act. For the residential customer class, the unprotected excess accumulated deferred income taxes will be returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, the unprotected excess accumulated deferred income taxes will be returned to customers over a 9-month period from April 2018 through December 2018. A true-up provision also was included, with any over- or under-returned unprotected excess accumulated deferred income taxes to be credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. Entergy Louisiana See the Form 10-K for a discussion of the activity of the LPSC and Entergy Louisiana after enactment of the Tax Act in December 2017. At the March 2018 LPSC Business and Executive Session, the LPSC staff provided a report on the tax-related rulemaking and invited additional interventions and comments before a proposed rule is issued. The LPSC staff commented that the proposed rule would likely set forth a generic mechanism that can be used by utilities to reflect the effects of the Tax Act in rates and a process by which utilities can propose utility specific treatment, if desired. See the “Formula Rate Plan Extension Request” discussion below. In the formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana will return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the parties agreed that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana would establish a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month until new base rates under the formula rate plan are established, and this regulatory liability will be returned to customers over the next formula rate plan rate-effective period. Entergy Louisiana recorded a $27 million regulatory liability in the first quarter 2018 pursuant to this provision of the settlement. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and analysis thereof as part of the formula rate plan review proceeding for the upcoming 2017 test year filing. Entergy Mississippi As discussed in the Form 10-K, after enactment of the Tax Act the MPSC ordered utilities, including Entergy Mississippi, that operate under a formula rate plan to file a description by February 26, 2018, of how the Tax Act will be reflected in the formula rate plan under which the utility operates. Entergy Mississippi's plan, as filed with the MPSC on February 26, 2018, included a request to reflect the changes related to the Tax Act in the 2018 formula rate plan filing. Entergy Mississippi filed its 2018 formula rate plan on March 15, 2018 and included a proposal to return all of its unprotected excess accumulated deferred income taxes to customers through rates or in exchange for other assets, or a combination of both, by the end of 2018. Also, in March 2018 the MPSC issued a subsequent order in its generic tax reform docket ordering utilities, including Entergy Mississippi, to explain the implementation of the utilities tax adjustment clause, or, in the alternative, why the tax adjustment clause is inapplicable; submit an analysis of the ratemaking effects of the Tax Act on current and future revenue requirements for rate schedules that include a gross-up for federal taxes; and make appropriate accounting entries to recognize the removal of excess deferred taxes from the balance of the utility’s accumulated deferred income tax account, or, in the alternative, explain why recording such entries is not appropriate. In April 2018, Entergy Mississippi filed its response to the MPSC stating that the tax adjustment clauses in its base rates are properly implemented through its formula rate plan. Entergy Mississippi also provided analysis of the ratemaking effects of the Tax Act. Entergy New Orleans As discussed in the Form 10-K, after enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. In March 2018, Entergy New Orleans filed its response to that resolution stating that the Tax Act reduced income tax expense from what is presently reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy has submitted filings of this type to the FERC. System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposes to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2018, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01547 per kWh to $0.01882 per kWh. The Arkansas Attorney General filed a response to Entergy Arkansas’s annual redetermination filing requesting that the APSC suspend the proposed tariff to investigate the amount of the redetermination or, alternatively, to allow recovery subject to refund. Among the reasons the Arkansas Attorney General cited for suspension were questions pertaining to how Entergy Arkansas forecasted sales and potential implications of the Tax Act. Entergy Arkansas replied to the Arkansas Attorney General’s filing and stated that, to the extent there are questions pertaining to its load forecasting or the operation of the energy cost recovery rider, those issues exceed the scope of the instant rate redetermination. Entergy Arkansas also stated that potential effects of the Tax Act are appropriately considered in the APSC’s separate proceeding looking at potential implications of the new tax law. The APSC general staff filed a reply to the Arkansas Attorney General’s filing and agreed that Entergy Arkansas’s filing complied with the terms of the energy cost recovery rider. In April 2018 the APSC issued an order declining to suspend Entergy Arkansas’s energy cost recovery rider rate and declining to require further investigation of the issues suggested by the Attorney General in the proceeding at this time. The redetermined rate became effective with the first billing cycle of April 2018. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in an open PUCT proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. The pending appeals did not stay the PUCT’s decision, and Entergy Texas refunded to customers the $10.9 million over a four-month period beginning with the first billing cycle of July 2016. The federal appeal of the PUCT’s January 2016 decision was heard in December 2016, and the Federal District Court granted Entergy Texas’s requested relief. In January 2017 the PUCT and an intervenor filed petitions for appeal to the U.S. Court of Appeals for the Fifth Circuit of the Federal District Court ruling. Oral argument was held before the U.S. Court of Appeals for the Fifth Circuit in February 2018. In April 2018 the U.S. Court of Appeals for the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. Entergy Texas is considering its legal options. The State District Court appeal of the PUCT’s January 2016 decision remains pending. In December 2017, Entergy Texas filed an application for a fuel refund of approximately $30.5 million for the months of May 2017 through October 2017. Also in December 2017, the PUCT’s ALJ approved the refund on an interim basis. For most customers, the refunds flowed through bills beginning January 2018 and continued through March 2018. The fuel refund was approved by the PUCT in March 2018. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC (Entergy Arkansas) Internal Restructuring As discussed in the Form 10-K, in November 2017, Entergy Arkansas filed an application with the APSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Arkansas to a new entity, which would ultimately be owned by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval by the APSC, the FERC, and the NRC. Entergy Arkansas also filed a notice with the Missouri Public Service Commission in December 2017 out of an abundance of caution, although Entergy Arkansas does not serve any retail customers in Missouri. In April 2018 the Missouri Public Service Commission approved Entergy Arkansas’s filing. If the appropriate approvals are obtained, Entergy Arkansas expects the restructuring will be consummated on or before December 1, 2018. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric Formula Rate Plan Extension Request In August 2017, Entergy Louisiana filed a request with the LPSC seeking to extend its formula rate plan for three years (2017-2019) with limited modifications of its terms. Those modifications include: a one-time resetting of base rates to the midpoint of the band at Entergy Louisiana’s authorized return on equity of 9.95% for the 2017 test year; narrowing of the formula rate plan bandwidth from a total of 160 basis points to 80 basis points; and a forward-looking mechanism that would allow Entergy Louisiana to recover certain transmission-related costs contemporaneously with when those projects begin delivering benefits to customers. Several parties intervened in the proceeding and all parties participated in settlement discussions. In April 2018 the LPSC approved an unopposed joint motion filed by Entergy Louisiana and the LPSC staff that settles the matter. The settlement extends the formula rate plan for three years, providing for rates through at least August 2021. In addition to retaining the major features of the traditional formula rate plan, substantive features of the extended formula rate plan include: • a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation; • a 9.8% target earned return on common equity for the 2018 and 2019 test years; • narrowing of the common equity bandwidth to plus or minus 60 basis points around the earned return on common equity; • a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity); • a framework for the flow back of certain tax benefits created by the Tax Act to customers, as described in “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above; and • a transmission recovery mechanism providing for the opportunity to recover certain transmission related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism. Union Power Station and Deactivation or Retirement Decisions for Entergy Louisiana Plants As discussed in the Form 10-K, as a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three-year term permitted by MISO. In March 2018 the LPSC adopted the ALJ’s recommended order finding that Entergy Louisiana did not demonstrate that its decision to permanently surrender transmission rights for the mothballed (not retired) Willow Glen 2 and 4 units was reasonable and that Entergy Louisiana should hold customers harmless from increased transmission expenses should those units be reactivated. Because no party or the LPSC suggested that Willow Glen 2 and 4 should be reactivated and because the cost to return those units to service far exceeds the revenue the units were expected to generate in MISO, Entergy Louisiana retired Willow Glen 2 and 4 in March 2018. Retail Rates - Gas 2017 Rate Stabilization Plan Filing In January 2018, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. The filing of the evaluation report for the test year 2017 reflected an earned return on common equity of 9.06% . This earned return is below the earnings sharing band of the rate stabilization plan and results in a rate increase of $0.1 million . Due to the enactment of the Tax Act in late-December 2017, Entergy Louisiana did not have adequate time to reflect the effects of this tax legislation in the rate stabilization plan. In April 2018 Entergy Louisiana filed a supplemental evaluation report for the test year ended September 2017, reflecting the effects of the Tax Act, including a proposal to use the unprotected excess accumulated deferred income taxes to offset storm restoration deferred operation and maintenance costs incurred by Entergy Louisiana in connection with the August 2016 flooding disaster in its gas service area. The supplemental filing reflects an earned return on common equity of 10.79% . If the as-filed rates from the supplemental filing are accepted by the LPSC, customers will receive a cost reduction of approximately $0.7 million effective with bills rendered on and after the first billing cycle of May 2018, as well as a $0.2 million prospective reduction in the gas infrastructure rider effective with bills rendered on and after the first billing cycle of July 2018. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2018, Entergy Mississippi submitted its formula rate plan 2018 test year filing and 2017 look-back filing showing Entergy Mississippi’s earned return for the historical 2017 calendar year and projected earned return for the 2018 calendar year, in large part as a result of the lower federal corporate income tax rate effective in 2018, to be within the formula rate plan bandwidth, resulting in no change in rates. The filing is currently subject to MPSC review. See “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above for additional discussion regarding the proposed treatment of the effects of the lower federal corporate income tax rate. Internal Restructuring In March 2018, Entergy Mississippi filed an application with the MPSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Mississippi to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval by the MPSC, the FERC, and the NRC. If the MPSC approves the restructuring by August 2018 and the restructuring closes on or before December 1, 2018, Entergy Mississippi proposed in its application to credit retail customers $27 million over six years, beginning in 2019. If the MPSC, the FERC, and the NRC approvals are obtained, Entergy Mississippi expects the restructuring will be consummated on or before December 1, 2018. It is currently contemplated that Entergy Mississippi would undertake a multi-step restructuring, which would include the following: • Entergy Mississippi would redeem its outstanding preferred stock, at the aggregate redemption price of approximately $21.2 million , including call premiums, plus accumulated and unpaid dividends, if any. • Entergy Mississippi would convert from a Mississippi corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy Mississippi will allocate substantially all of its assets to a new subsidiary, Entergy Mississippi Power and Light, LLC, a Texas limited liability company (Entergy Mississippi Power and Light), and Entergy Mississippi Power and Light will assume substantially all of the liabilities of Entergy Mississippi, in a transaction regarded as a merger under the TXBOC. Entergy Mississippi will remain in existence and hold the membership interests in Entergy Mississippi Power and Light. • Entergy Mississippi will contribute the membership interests in Entergy Mississippi Power and Light to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy Mississippi Power and Light will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC. • Entergy Mississippi will change its name to Entergy Utility Enterprises, Inc., and Entergy Mississippi Power and Light will then change its name to Entergy Mississippi, LLC. Upon the completion of the restructuring, Entergy Mississippi, LLC will hold substantially all of the assets, and will have assumed substantially all of the liabilities, of Entergy Mississippi. Entergy Mississippi may modify or supplement the steps to be taken to effectuate the restructuring. Advanced Metering Infrastructure (AMI) Filings Entergy New Orleans As discussed in the Form 10-K, in February 2018 the City Council approved Entergy New Orleans’s application seeking a finding that Entergy New Orleans’s deployment of advanced electric and gas metering infrastructure is in the public interest. Deployment of the information technology infrastructure began in 2017 and deployment of the communications network is expected to begin later in 2018. In April 2018 the City Council adopted a resolution directing Entergy New Orleans to explore the options for accelerating the deployment of AMI. Entergy New Orleans is required to report its findings to the City Council by June 2018. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, in August 2017 the D.C. Circuit issued a decision denying the LPSC’s appeal of the FERC’s October 2011 and February 2014 orders, but also granting the request by all parties to the appeal for remand and agency reconsideration on the issue of whether the operating companies should be required to issue refunds for the 20-month period from September 2001 to May 2003. The matter was remanded back to the FERC and, in March 2018, the LPSC filed at the FERC its initial brief addressing the issue that the D.C. Circuit remanded back to the FERC in August 2017. In its brief, the LPSC argued that the FERC should require the Utility operating companies to issue refunds for the 20-month refund period from September 2001 to May 2003. Rough Production Cost Equalization Rates Consolidated 2011, 2012, 2013, and 2014 Rate Filing Proceedings As discussed in the Form 10-K, in December 2014 the FERC consolidated the 2011, 2012, 2013, and 2014 rate filings for settlement and hearing procedures. In May 2015, Entergy filed direct testimony in the consolidated rate filings and the LPSC filed direct testimony concerning its complaint proceeding that is consolidated with the rate filings, challenging certain components of the pending bandwidth calculations for prior years. Hearings occurred in November 2015, and the ALJ issued an initial decision in July 2016. In the initial decision, the ALJ generally agreed with Entergy’s bandwidth calculations with one exception on the accounting related to the Waterford 3 sale/leaseback. In March 2018 the FERC issued an order affirming the initial decision. In April 2018 the LPSC requested rehearing of the FERC’s March 2018 order affirming the ALJ’s initial decision. Based on the March 2018 FERC order, the following preliminary estimated payments/receipts were recorded in March 2018 among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $6 Entergy New Orleans $2 Entergy Texas ($8) Entergy Services expects to file in May 2018 the bandwidth true-up payments and receipts for the 2011-2014 rate filings. Interruptible Load Proceedings See the Form 10-K for a discussion of the interruptible load proceedings. As discussed in the Form 10-K, the LPSC appealed the April and September 2016 orders to the D.C. Circuit. In March 2018 the D.C. Circuit issued an order denying the LPSC’s appeal and affirming the FERC’s decision that it would be inequitable to award refunds in the proceeding. In April 2018 the LPSC sought rehearing en banc of the D.C. Circuit’s order denying the LPSC’s appeal. Complaint Against System Energy As discussed in the Form 10-K, in January 2017 the APSC and the MPSC filed a complaint requesting that the FERC establish proceedings to investigate System Energy’s return on equity under the Unit Power Sales Agreement, establish a refund effective date, and establish a new and lower return on equity. In September 2017 the FERC established a refund effective date of January 23, 2017, consolidated the return on equity complaint with the proceeding described in “ Unit Power Sales Agreement ” in the Form 10-K, and directed the parties to engage in settlement proceedings before an ALJ. Settlement discussions are ongoing. The refund effective date in connection with the APSC/MPSC complaint expired on April 23, 2018. In April 2018 the LPSC filed a complaint with the FERC against System Energy seeking an additional fifteen-month refund period. The LPSC complaint requests similar relief from the FERC with respect to System Energy’s return on equity and also requests the FERC to investigate System Energy’s capital structure and application of System Energy’s allowed depreciation rates to plant additions associated with the Grand Gulf sale/leaseback transactions. System Energy expects to answer the LPSC complaint in May 2018.
Entergy Mississippi [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements in the Form 10-K for discussion of the effects of the enactment in December 2017 of the Tax Cuts and Jobs Act (the Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. After assessing the activity described in more detail below regarding the proposals the Registrant Subsidiaries have made to their regulators for the return of unprotected excess accumulated deferred income taxes to customers, in the first quarter 2018, Entergy and each of the Registrant Subsidiaries reclassified from the regulatory liability for income taxes to current liabilities the portion of their unprotected excess accumulated deferred income taxes that they expect to return to customers over the next twelve months. Entergy Arkansas See the Form 10-K for a discussion of the activity of the APSC and Entergy Arkansas after enactment of the Tax Act in December 2017. The APSC granted Entergy Arkansas’s request for clarification regarding the APSC’s order issued after enactment of the Tax Act. The APSC states that its order was not a final determination and that the APSC has made no decision at this time on the appropriate final accounting or ratemaking treatment of the amounts in question. Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff docket in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits associated with the Tax Act. For the residential customer class, the unprotected excess accumulated deferred income taxes will be returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, the unprotected excess accumulated deferred income taxes will be returned to customers over a 9-month period from April 2018 through December 2018. A true-up provision also was included, with any over- or under-returned unprotected excess accumulated deferred income taxes to be credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. Entergy Louisiana See the Form 10-K for a discussion of the activity of the LPSC and Entergy Louisiana after enactment of the Tax Act in December 2017. At the March 2018 LPSC Business and Executive Session, the LPSC staff provided a report on the tax-related rulemaking and invited additional interventions and comments before a proposed rule is issued. The LPSC staff commented that the proposed rule would likely set forth a generic mechanism that can be used by utilities to reflect the effects of the Tax Act in rates and a process by which utilities can propose utility specific treatment, if desired. See the “Formula Rate Plan Extension Request” discussion below. In the formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana will return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the parties agreed that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana would establish a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month until new base rates under the formula rate plan are established, and this regulatory liability will be returned to customers over the next formula rate plan rate-effective period. Entergy Louisiana recorded a $27 million regulatory liability in the first quarter 2018 pursuant to this provision of the settlement. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and analysis thereof as part of the formula rate plan review proceeding for the upcoming 2017 test year filing. Entergy Mississippi As discussed in the Form 10-K, after enactment of the Tax Act the MPSC ordered utilities, including Entergy Mississippi, that operate under a formula rate plan to file a description by February 26, 2018, of how the Tax Act will be reflected in the formula rate plan under which the utility operates. Entergy Mississippi's plan, as filed with the MPSC on February 26, 2018, included a request to reflect the changes related to the Tax Act in the 2018 formula rate plan filing. Entergy Mississippi filed its 2018 formula rate plan on March 15, 2018 and included a proposal to return all of its unprotected excess accumulated deferred income taxes to customers through rates or in exchange for other assets, or a combination of both, by the end of 2018. Also, in March 2018 the MPSC issued a subsequent order in its generic tax reform docket ordering utilities, including Entergy Mississippi, to explain the implementation of the utilities tax adjustment clause, or, in the alternative, why the tax adjustment clause is inapplicable; submit an analysis of the ratemaking effects of the Tax Act on current and future revenue requirements for rate schedules that include a gross-up for federal taxes; and make appropriate accounting entries to recognize the removal of excess deferred taxes from the balance of the utility’s accumulated deferred income tax account, or, in the alternative, explain why recording such entries is not appropriate. In April 2018, Entergy Mississippi filed its response to the MPSC stating that the tax adjustment clauses in its base rates are properly implemented through its formula rate plan. Entergy Mississippi also provided analysis of the ratemaking effects of the Tax Act. Entergy New Orleans As discussed in the Form 10-K, after enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. In March 2018, Entergy New Orleans filed its response to that resolution stating that the Tax Act reduced income tax expense from what is presently reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy has submitted filings of this type to the FERC. System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposes to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2018, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01547 per kWh to $0.01882 per kWh. The Arkansas Attorney General filed a response to Entergy Arkansas’s annual redetermination filing requesting that the APSC suspend the proposed tariff to investigate the amount of the redetermination or, alternatively, to allow recovery subject to refund. Among the reasons the Arkansas Attorney General cited for suspension were questions pertaining to how Entergy Arkansas forecasted sales and potential implications of the Tax Act. Entergy Arkansas replied to the Arkansas Attorney General’s filing and stated that, to the extent there are questions pertaining to its load forecasting or the operation of the energy cost recovery rider, those issues exceed the scope of the instant rate redetermination. Entergy Arkansas also stated that potential effects of the Tax Act are appropriately considered in the APSC’s separate proceeding looking at potential implications of the new tax law. The APSC general staff filed a reply to the Arkansas Attorney General’s filing and agreed that Entergy Arkansas’s filing complied with the terms of the energy cost recovery rider. In April 2018 the APSC issued an order declining to suspend Entergy Arkansas’s energy cost recovery rider rate and declining to require further investigation of the issues suggested by the Attorney General in the proceeding at this time. The redetermined rate became effective with the first billing cycle of April 2018. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in an open PUCT proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. The pending appeals did not stay the PUCT’s decision, and Entergy Texas refunded to customers the $10.9 million over a four-month period beginning with the first billing cycle of July 2016. The federal appeal of the PUCT’s January 2016 decision was heard in December 2016, and the Federal District Court granted Entergy Texas’s requested relief. In January 2017 the PUCT and an intervenor filed petitions for appeal to the U.S. Court of Appeals for the Fifth Circuit of the Federal District Court ruling. Oral argument was held before the U.S. Court of Appeals for the Fifth Circuit in February 2018. In April 2018 the U.S. Court of Appeals for the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. Entergy Texas is considering its legal options. The State District Court appeal of the PUCT’s January 2016 decision remains pending. In December 2017, Entergy Texas filed an application for a fuel refund of approximately $30.5 million for the months of May 2017 through October 2017. Also in December 2017, the PUCT’s ALJ approved the refund on an interim basis. For most customers, the refunds flowed through bills beginning January 2018 and continued through March 2018. The fuel refund was approved by the PUCT in March 2018. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC (Entergy Arkansas) Internal Restructuring As discussed in the Form 10-K, in November 2017, Entergy Arkansas filed an application with the APSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Arkansas to a new entity, which would ultimately be owned by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval by the APSC, the FERC, and the NRC. Entergy Arkansas also filed a notice with the Missouri Public Service Commission in December 2017 out of an abundance of caution, although Entergy Arkansas does not serve any retail customers in Missouri. In April 2018 the Missouri Public Service Commission approved Entergy Arkansas’s filing. If the appropriate approvals are obtained, Entergy Arkansas expects the restructuring will be consummated on or before December 1, 2018. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric Formula Rate Plan Extension Request In August 2017, Entergy Louisiana filed a request with the LPSC seeking to extend its formula rate plan for three years (2017-2019) with limited modifications of its terms. Those modifications include: a one-time resetting of base rates to the midpoint of the band at Entergy Louisiana’s authorized return on equity of 9.95% for the 2017 test year; narrowing of the formula rate plan bandwidth from a total of 160 basis points to 80 basis points; and a forward-looking mechanism that would allow Entergy Louisiana to recover certain transmission-related costs contemporaneously with when those projects begin delivering benefits to customers. Several parties intervened in the proceeding and all parties participated in settlement discussions. In April 2018 the LPSC approved an unopposed joint motion filed by Entergy Louisiana and the LPSC staff that settles the matter. The settlement extends the formula rate plan for three years, providing for rates through at least August 2021. In addition to retaining the major features of the traditional formula rate plan, substantive features of the extended formula rate plan include: • a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation; • a 9.8% target earned return on common equity for the 2018 and 2019 test years; • narrowing of the common equity bandwidth to plus or minus 60 basis points around the earned return on common equity; • a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity); • a framework for the flow back of certain tax benefits created by the Tax Act to customers, as described in “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above; and • a transmission recovery mechanism providing for the opportunity to recover certain transmission related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism. Union Power Station and Deactivation or Retirement Decisions for Entergy Louisiana Plants As discussed in the Form 10-K, as a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three-year term permitted by MISO. In March 2018 the LPSC adopted the ALJ’s recommended order finding that Entergy Louisiana did not demonstrate that its decision to permanently surrender transmission rights for the mothballed (not retired) Willow Glen 2 and 4 units was reasonable and that Entergy Louisiana should hold customers harmless from increased transmission expenses should those units be reactivated. Because no party or the LPSC suggested that Willow Glen 2 and 4 should be reactivated and because the cost to return those units to service far exceeds the revenue the units were expected to generate in MISO, Entergy Louisiana retired Willow Glen 2 and 4 in March 2018. Retail Rates - Gas 2017 Rate Stabilization Plan Filing In January 2018, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. The filing of the evaluation report for the test year 2017 reflected an earned return on common equity of 9.06% . This earned return is below the earnings sharing band of the rate stabilization plan and results in a rate increase of $0.1 million . Due to the enactment of the Tax Act in late-December 2017, Entergy Louisiana did not have adequate time to reflect the effects of this tax legislation in the rate stabilization plan. In April 2018 Entergy Louisiana filed a supplemental evaluation report for the test year ended September 2017, reflecting the effects of the Tax Act, including a proposal to use the unprotected excess accumulated deferred income taxes to offset storm restoration deferred operation and maintenance costs incurred by Entergy Louisiana in connection with the August 2016 flooding disaster in its gas service area. The supplemental filing reflects an earned return on common equity of 10.79% . If the as-filed rates from the supplemental filing are accepted by the LPSC, customers will receive a cost reduction of approximately $0.7 million effective with bills rendered on and after the first billing cycle of May 2018, as well as a $0.2 million prospective reduction in the gas infrastructure rider effective with bills rendered on and after the first billing cycle of July 2018. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2018, Entergy Mississippi submitted its formula rate plan 2018 test year filing and 2017 look-back filing showing Entergy Mississippi’s earned return for the historical 2017 calendar year and projected earned return for the 2018 calendar year, in large part as a result of the lower federal corporate income tax rate effective in 2018, to be within the formula rate plan bandwidth, resulting in no change in rates. The filing is currently subject to MPSC review. See “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above for additional discussion regarding the proposed treatment of the effects of the lower federal corporate income tax rate. Internal Restructuring In March 2018, Entergy Mississippi filed an application with the MPSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Mississippi to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval by the MPSC, the FERC, and the NRC. If the MPSC approves the restructuring by August 2018 and the restructuring closes on or before December 1, 2018, Entergy Mississippi proposed in its application to credit retail customers $27 million over six years, beginning in 2019. If the MPSC, the FERC, and the NRC approvals are obtained, Entergy Mississippi expects the restructuring will be consummated on or before December 1, 2018. It is currently contemplated that Entergy Mississippi would undertake a multi-step restructuring, which would include the following: • Entergy Mississippi would redeem its outstanding preferred stock, at the aggregate redemption price of approximately $21.2 million , including call premiums, plus accumulated and unpaid dividends, if any. • Entergy Mississippi would convert from a Mississippi corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy Mississippi will allocate substantially all of its assets to a new subsidiary, Entergy Mississippi Power and Light, LLC, a Texas limited liability company (Entergy Mississippi Power and Light), and Entergy Mississippi Power and Light will assume substantially all of the liabilities of Entergy Mississippi, in a transaction regarded as a merger under the TXBOC. Entergy Mississippi will remain in existence and hold the membership interests in Entergy Mississippi Power and Light. • Entergy Mississippi will contribute the membership interests in Entergy Mississippi Power and Light to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy Mississippi Power and Light will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC. • Entergy Mississippi will change its name to Entergy Utility Enterprises, Inc., and Entergy Mississippi Power and Light will then change its name to Entergy Mississippi, LLC. Upon the completion of the restructuring, Entergy Mississippi, LLC will hold substantially all of the assets, and will have assumed substantially all of the liabilities, of Entergy Mississippi. Entergy Mississippi may modify or supplement the steps to be taken to effectuate the restructuring. Advanced Metering Infrastructure (AMI) Filings Entergy New Orleans As discussed in the Form 10-K, in February 2018 the City Council approved Entergy New Orleans’s application seeking a finding that Entergy New Orleans’s deployment of advanced electric and gas metering infrastructure is in the public interest. Deployment of the information technology infrastructure began in 2017 and deployment of the communications network is expected to begin later in 2018. In April 2018 the City Council adopted a resolution directing Entergy New Orleans to explore the options for accelerating the deployment of AMI. Entergy New Orleans is required to report its findings to the City Council by June 2018. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, in August 2017 the D.C. Circuit issued a decision denying the LPSC’s appeal of the FERC’s October 2011 and February 2014 orders, but also granting the request by all parties to the appeal for remand and agency reconsideration on the issue of whether the operating companies should be required to issue refunds for the 20-month period from September 2001 to May 2003. The matter was remanded back to the FERC and, in March 2018, the LPSC filed at the FERC its initial brief addressing the issue that the D.C. Circuit remanded back to the FERC in August 2017. In its brief, the LPSC argued that the FERC should require the Utility operating companies to issue refunds for the 20-month refund period from September 2001 to May 2003. Rough Production Cost Equalization Rates Consolidated 2011, 2012, 2013, and 2014 Rate Filing Proceedings As discussed in the Form 10-K, in December 2014 the FERC consolidated the 2011, 2012, 2013, and 2014 rate filings for settlement and hearing procedures. In May 2015, Entergy filed direct testimony in the consolidated rate filings and the LPSC filed direct testimony concerning its complaint proceeding that is consolidated with the rate filings, challenging certain components of the pending bandwidth calculations for prior years. Hearings occurred in November 2015, and the ALJ issued an initial decision in July 2016. In the initial decision, the ALJ generally agreed with Entergy’s bandwidth calculations with one exception on the accounting related to the Waterford 3 sale/leaseback. In March 2018 the FERC issued an order affirming the initial decision. In April 2018 the LPSC requested rehearing of the FERC’s March 2018 order affirming the ALJ’s initial decision. Based on the March 2018 FERC order, the following preliminary estimated payments/receipts were recorded in March 2018 among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $6 Entergy New Orleans $2 Entergy Texas ($8) Entergy Services expects to file in May 2018 the bandwidth true-up payments and receipts for the 2011-2014 rate filings. Interruptible Load Proceedings See the Form 10-K for a discussion of the interruptible load proceedings. As discussed in the Form 10-K, the LPSC appealed the April and September 2016 orders to the D.C. Circuit. In March 2018 the D.C. Circuit issued an order denying the LPSC’s appeal and affirming the FERC’s decision that it would be inequitable to award refunds in the proceeding. In April 2018 the LPSC sought rehearing en banc of the D.C. Circuit’s order denying the LPSC’s appeal. Complaint Against System Energy As discussed in the Form 10-K, in January 2017 the APSC and the MPSC filed a complaint requesting that the FERC establish proceedings to investigate System Energy’s return on equity under the Unit Power Sales Agreement, establish a refund effective date, and establish a new and lower return on equity. In September 2017 the FERC established a refund effective date of January 23, 2017, consolidated the return on equity complaint with the proceeding described in “ Unit Power Sales Agreement ” in the Form 10-K, and directed the parties to engage in settlement proceedings before an ALJ. Settlement discussions are ongoing. The refund effective date in connection with the APSC/MPSC complaint expired on April 23, 2018. In April 2018 the LPSC filed a complaint with the FERC against System Energy seeking an additional fifteen-month refund period. The LPSC complaint requests similar relief from the FERC with respect to System Energy’s return on equity and also requests the FERC to investigate System Energy’s capital structure and application of System Energy’s allowed depreciation rates to plant additions associated with the Grand Gulf sale/leaseback transactions. System Energy expects to answer the LPSC complaint in May 2018.
Entergy New Orleans [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements in the Form 10-K for discussion of the effects of the enactment in December 2017 of the Tax Cuts and Jobs Act (the Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. After assessing the activity described in more detail below regarding the proposals the Registrant Subsidiaries have made to their regulators for the return of unprotected excess accumulated deferred income taxes to customers, in the first quarter 2018, Entergy and each of the Registrant Subsidiaries reclassified from the regulatory liability for income taxes to current liabilities the portion of their unprotected excess accumulated deferred income taxes that they expect to return to customers over the next twelve months. Entergy Arkansas See the Form 10-K for a discussion of the activity of the APSC and Entergy Arkansas after enactment of the Tax Act in December 2017. The APSC granted Entergy Arkansas’s request for clarification regarding the APSC’s order issued after enactment of the Tax Act. The APSC states that its order was not a final determination and that the APSC has made no decision at this time on the appropriate final accounting or ratemaking treatment of the amounts in question. Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff docket in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits associated with the Tax Act. For the residential customer class, the unprotected excess accumulated deferred income taxes will be returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, the unprotected excess accumulated deferred income taxes will be returned to customers over a 9-month period from April 2018 through December 2018. A true-up provision also was included, with any over- or under-returned unprotected excess accumulated deferred income taxes to be credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. Entergy Louisiana See the Form 10-K for a discussion of the activity of the LPSC and Entergy Louisiana after enactment of the Tax Act in December 2017. At the March 2018 LPSC Business and Executive Session, the LPSC staff provided a report on the tax-related rulemaking and invited additional interventions and comments before a proposed rule is issued. The LPSC staff commented that the proposed rule would likely set forth a generic mechanism that can be used by utilities to reflect the effects of the Tax Act in rates and a process by which utilities can propose utility specific treatment, if desired. See the “Formula Rate Plan Extension Request” discussion below. In the formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana will return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the parties agreed that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana would establish a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month until new base rates under the formula rate plan are established, and this regulatory liability will be returned to customers over the next formula rate plan rate-effective period. Entergy Louisiana recorded a $27 million regulatory liability in the first quarter 2018 pursuant to this provision of the settlement. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and analysis thereof as part of the formula rate plan review proceeding for the upcoming 2017 test year filing. Entergy Mississippi As discussed in the Form 10-K, after enactment of the Tax Act the MPSC ordered utilities, including Entergy Mississippi, that operate under a formula rate plan to file a description by February 26, 2018, of how the Tax Act will be reflected in the formula rate plan under which the utility operates. Entergy Mississippi's plan, as filed with the MPSC on February 26, 2018, included a request to reflect the changes related to the Tax Act in the 2018 formula rate plan filing. Entergy Mississippi filed its 2018 formula rate plan on March 15, 2018 and included a proposal to return all of its unprotected excess accumulated deferred income taxes to customers through rates or in exchange for other assets, or a combination of both, by the end of 2018. Also, in March 2018 the MPSC issued a subsequent order in its generic tax reform docket ordering utilities, including Entergy Mississippi, to explain the implementation of the utilities tax adjustment clause, or, in the alternative, why the tax adjustment clause is inapplicable; submit an analysis of the ratemaking effects of the Tax Act on current and future revenue requirements for rate schedules that include a gross-up for federal taxes; and make appropriate accounting entries to recognize the removal of excess deferred taxes from the balance of the utility’s accumulated deferred income tax account, or, in the alternative, explain why recording such entries is not appropriate. In April 2018, Entergy Mississippi filed its response to the MPSC stating that the tax adjustment clauses in its base rates are properly implemented through its formula rate plan. Entergy Mississippi also provided analysis of the ratemaking effects of the Tax Act. Entergy New Orleans As discussed in the Form 10-K, after enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. In March 2018, Entergy New Orleans filed its response to that resolution stating that the Tax Act reduced income tax expense from what is presently reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy has submitted filings of this type to the FERC. System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposes to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2018, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01547 per kWh to $0.01882 per kWh. The Arkansas Attorney General filed a response to Entergy Arkansas’s annual redetermination filing requesting that the APSC suspend the proposed tariff to investigate the amount of the redetermination or, alternatively, to allow recovery subject to refund. Among the reasons the Arkansas Attorney General cited for suspension were questions pertaining to how Entergy Arkansas forecasted sales and potential implications of the Tax Act. Entergy Arkansas replied to the Arkansas Attorney General’s filing and stated that, to the extent there are questions pertaining to its load forecasting or the operation of the energy cost recovery rider, those issues exceed the scope of the instant rate redetermination. Entergy Arkansas also stated that potential effects of the Tax Act are appropriately considered in the APSC’s separate proceeding looking at potential implications of the new tax law. The APSC general staff filed a reply to the Arkansas Attorney General’s filing and agreed that Entergy Arkansas’s filing complied with the terms of the energy cost recovery rider. In April 2018 the APSC issued an order declining to suspend Entergy Arkansas’s energy cost recovery rider rate and declining to require further investigation of the issues suggested by the Attorney General in the proceeding at this time. The redetermined rate became effective with the first billing cycle of April 2018. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in an open PUCT proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. The pending appeals did not stay the PUCT’s decision, and Entergy Texas refunded to customers the $10.9 million over a four-month period beginning with the first billing cycle of July 2016. The federal appeal of the PUCT’s January 2016 decision was heard in December 2016, and the Federal District Court granted Entergy Texas’s requested relief. In January 2017 the PUCT and an intervenor filed petitions for appeal to the U.S. Court of Appeals for the Fifth Circuit of the Federal District Court ruling. Oral argument was held before the U.S. Court of Appeals for the Fifth Circuit in February 2018. In April 2018 the U.S. Court of Appeals for the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. Entergy Texas is considering its legal options. The State District Court appeal of the PUCT’s January 2016 decision remains pending. In December 2017, Entergy Texas filed an application for a fuel refund of approximately $30.5 million for the months of May 2017 through October 2017. Also in December 2017, the PUCT’s ALJ approved the refund on an interim basis. For most customers, the refunds flowed through bills beginning January 2018 and continued through March 2018. The fuel refund was approved by the PUCT in March 2018. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC (Entergy Arkansas) Internal Restructuring As discussed in the Form 10-K, in November 2017, Entergy Arkansas filed an application with the APSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Arkansas to a new entity, which would ultimately be owned by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval by the APSC, the FERC, and the NRC. Entergy Arkansas also filed a notice with the Missouri Public Service Commission in December 2017 out of an abundance of caution, although Entergy Arkansas does not serve any retail customers in Missouri. In April 2018 the Missouri Public Service Commission approved Entergy Arkansas’s filing. If the appropriate approvals are obtained, Entergy Arkansas expects the restructuring will be consummated on or before December 1, 2018. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric Formula Rate Plan Extension Request In August 2017, Entergy Louisiana filed a request with the LPSC seeking to extend its formula rate plan for three years (2017-2019) with limited modifications of its terms. Those modifications include: a one-time resetting of base rates to the midpoint of the band at Entergy Louisiana’s authorized return on equity of 9.95% for the 2017 test year; narrowing of the formula rate plan bandwidth from a total of 160 basis points to 80 basis points; and a forward-looking mechanism that would allow Entergy Louisiana to recover certain transmission-related costs contemporaneously with when those projects begin delivering benefits to customers. Several parties intervened in the proceeding and all parties participated in settlement discussions. In April 2018 the LPSC approved an unopposed joint motion filed by Entergy Louisiana and the LPSC staff that settles the matter. The settlement extends the formula rate plan for three years, providing for rates through at least August 2021. In addition to retaining the major features of the traditional formula rate plan, substantive features of the extended formula rate plan include: • a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation; • a 9.8% target earned return on common equity for the 2018 and 2019 test years; • narrowing of the common equity bandwidth to plus or minus 60 basis points around the earned return on common equity; • a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity); • a framework for the flow back of certain tax benefits created by the Tax Act to customers, as described in “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above; and • a transmission recovery mechanism providing for the opportunity to recover certain transmission related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism. Union Power Station and Deactivation or Retirement Decisions for Entergy Louisiana Plants As discussed in the Form 10-K, as a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three-year term permitted by MISO. In March 2018 the LPSC adopted the ALJ’s recommended order finding that Entergy Louisiana did not demonstrate that its decision to permanently surrender transmission rights for the mothballed (not retired) Willow Glen 2 and 4 units was reasonable and that Entergy Louisiana should hold customers harmless from increased transmission expenses should those units be reactivated. Because no party or the LPSC suggested that Willow Glen 2 and 4 should be reactivated and because the cost to return those units to service far exceeds the revenue the units were expected to generate in MISO, Entergy Louisiana retired Willow Glen 2 and 4 in March 2018. Retail Rates - Gas 2017 Rate Stabilization Plan Filing In January 2018, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. The filing of the evaluation report for the test year 2017 reflected an earned return on common equity of 9.06% . This earned return is below the earnings sharing band of the rate stabilization plan and results in a rate increase of $0.1 million . Due to the enactment of the Tax Act in late-December 2017, Entergy Louisiana did not have adequate time to reflect the effects of this tax legislation in the rate stabilization plan. In April 2018 Entergy Louisiana filed a supplemental evaluation report for the test year ended September 2017, reflecting the effects of the Tax Act, including a proposal to use the unprotected excess accumulated deferred income taxes to offset storm restoration deferred operation and maintenance costs incurred by Entergy Louisiana in connection with the August 2016 flooding disaster in its gas service area. The supplemental filing reflects an earned return on common equity of 10.79% . If the as-filed rates from the supplemental filing are accepted by the LPSC, customers will receive a cost reduction of approximately $0.7 million effective with bills rendered on and after the first billing cycle of May 2018, as well as a $0.2 million prospective reduction in the gas infrastructure rider effective with bills rendered on and after the first billing cycle of July 2018. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2018, Entergy Mississippi submitted its formula rate plan 2018 test year filing and 2017 look-back filing showing Entergy Mississippi’s earned return for the historical 2017 calendar year and projected earned return for the 2018 calendar year, in large part as a result of the lower federal corporate income tax rate effective in 2018, to be within the formula rate plan bandwidth, resulting in no change in rates. The filing is currently subject to MPSC review. See “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above for additional discussion regarding the proposed treatment of the effects of the lower federal corporate income tax rate. Internal Restructuring In March 2018, Entergy Mississippi filed an application with the MPSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Mississippi to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval by the MPSC, the FERC, and the NRC. If the MPSC approves the restructuring by August 2018 and the restructuring closes on or before December 1, 2018, Entergy Mississippi proposed in its application to credit retail customers $27 million over six years, beginning in 2019. If the MPSC, the FERC, and the NRC approvals are obtained, Entergy Mississippi expects the restructuring will be consummated on or before December 1, 2018. It is currently contemplated that Entergy Mississippi would undertake a multi-step restructuring, which would include the following: • Entergy Mississippi would redeem its outstanding preferred stock, at the aggregate redemption price of approximately $21.2 million , including call premiums, plus accumulated and unpaid dividends, if any. • Entergy Mississippi would convert from a Mississippi corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy Mississippi will allocate substantially all of its assets to a new subsidiary, Entergy Mississippi Power and Light, LLC, a Texas limited liability company (Entergy Mississippi Power and Light), and Entergy Mississippi Power and Light will assume substantially all of the liabilities of Entergy Mississippi, in a transaction regarded as a merger under the TXBOC. Entergy Mississippi will remain in existence and hold the membership interests in Entergy Mississippi Power and Light. • Entergy Mississippi will contribute the membership interests in Entergy Mississippi Power and Light to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy Mississippi Power and Light will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC. • Entergy Mississippi will change its name to Entergy Utility Enterprises, Inc., and Entergy Mississippi Power and Light will then change its name to Entergy Mississippi, LLC. Upon the completion of the restructuring, Entergy Mississippi, LLC will hold substantially all of the assets, and will have assumed substantially all of the liabilities, of Entergy Mississippi. Entergy Mississippi may modify or supplement the steps to be taken to effectuate the restructuring. Advanced Metering Infrastructure (AMI) Filings Entergy New Orleans As discussed in the Form 10-K, in February 2018 the City Council approved Entergy New Orleans’s application seeking a finding that Entergy New Orleans’s deployment of advanced electric and gas metering infrastructure is in the public interest. Deployment of the information technology infrastructure began in 2017 and deployment of the communications network is expected to begin later in 2018. In April 2018 the City Council adopted a resolution directing Entergy New Orleans to explore the options for accelerating the deployment of AMI. Entergy New Orleans is required to report its findings to the City Council by June 2018. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, in August 2017 the D.C. Circuit issued a decision denying the LPSC’s appeal of the FERC’s October 2011 and February 2014 orders, but also granting the request by all parties to the appeal for remand and agency reconsideration on the issue of whether the operating companies should be required to issue refunds for the 20-month period from September 2001 to May 2003. The matter was remanded back to the FERC and, in March 2018, the LPSC filed at the FERC its initial brief addressing the issue that the D.C. Circuit remanded back to the FERC in August 2017. In its brief, the LPSC argued that the FERC should require the Utility operating companies to issue refunds for the 20-month refund period from September 2001 to May 2003. Rough Production Cost Equalization Rates Consolidated 2011, 2012, 2013, and 2014 Rate Filing Proceedings As discussed in the Form 10-K, in December 2014 the FERC consolidated the 2011, 2012, 2013, and 2014 rate filings for settlement and hearing procedures. In May 2015, Entergy filed direct testimony in the consolidated rate filings and the LPSC filed direct testimony concerning its complaint proceeding that is consolidated with the rate filings, challenging certain components of the pending bandwidth calculations for prior years. Hearings occurred in November 2015, and the ALJ issued an initial decision in July 2016. In the initial decision, the ALJ generally agreed with Entergy’s bandwidth calculations with one exception on the accounting related to the Waterford 3 sale/leaseback. In March 2018 the FERC issued an order affirming the initial decision. In April 2018 the LPSC requested rehearing of the FERC’s March 2018 order affirming the ALJ’s initial decision. Based on the March 2018 FERC order, the following preliminary estimated payments/receipts were recorded in March 2018 among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $6 Entergy New Orleans $2 Entergy Texas ($8) Entergy Services expects to file in May 2018 the bandwidth true-up payments and receipts for the 2011-2014 rate filings. Interruptible Load Proceedings See the Form 10-K for a discussion of the interruptible load proceedings. As discussed in the Form 10-K, the LPSC appealed the April and September 2016 orders to the D.C. Circuit. In March 2018 the D.C. Circuit issued an order denying the LPSC’s appeal and affirming the FERC’s decision that it would be inequitable to award refunds in the proceeding. In April 2018 the LPSC sought rehearing en banc of the D.C. Circuit’s order denying the LPSC’s appeal. Complaint Against System Energy As discussed in the Form 10-K, in January 2017 the APSC and the MPSC filed a complaint requesting that the FERC establish proceedings to investigate System Energy’s return on equity under the Unit Power Sales Agreement, establish a refund effective date, and establish a new and lower return on equity. In September 2017 the FERC established a refund effective date of January 23, 2017, consolidated the return on equity complaint with the proceeding described in “ Unit Power Sales Agreement ” in the Form 10-K, and directed the parties to engage in settlement proceedings before an ALJ. Settlement discussions are ongoing. The refund effective date in connection with the APSC/MPSC complaint expired on April 23, 2018. In April 2018 the LPSC filed a complaint with the FERC against System Energy seeking an additional fifteen-month refund period. The LPSC complaint requests similar relief from the FERC with respect to System Energy’s return on equity and also requests the FERC to investigate System Energy’s capital structure and application of System Energy’s allowed depreciation rates to plant additions associated with the Grand Gulf sale/leaseback transactions. System Energy expects to answer the LPSC complaint in May 2018.
Entergy Texas [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements in the Form 10-K for discussion of the effects of the enactment in December 2017 of the Tax Cuts and Jobs Act (the Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. After assessing the activity described in more detail below regarding the proposals the Registrant Subsidiaries have made to their regulators for the return of unprotected excess accumulated deferred income taxes to customers, in the first quarter 2018, Entergy and each of the Registrant Subsidiaries reclassified from the regulatory liability for income taxes to current liabilities the portion of their unprotected excess accumulated deferred income taxes that they expect to return to customers over the next twelve months. Entergy Arkansas See the Form 10-K for a discussion of the activity of the APSC and Entergy Arkansas after enactment of the Tax Act in December 2017. The APSC granted Entergy Arkansas’s request for clarification regarding the APSC’s order issued after enactment of the Tax Act. The APSC states that its order was not a final determination and that the APSC has made no decision at this time on the appropriate final accounting or ratemaking treatment of the amounts in question. Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff docket in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits associated with the Tax Act. For the residential customer class, the unprotected excess accumulated deferred income taxes will be returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, the unprotected excess accumulated deferred income taxes will be returned to customers over a 9-month period from April 2018 through December 2018. A true-up provision also was included, with any over- or under-returned unprotected excess accumulated deferred income taxes to be credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. Entergy Louisiana See the Form 10-K for a discussion of the activity of the LPSC and Entergy Louisiana after enactment of the Tax Act in December 2017. At the March 2018 LPSC Business and Executive Session, the LPSC staff provided a report on the tax-related rulemaking and invited additional interventions and comments before a proposed rule is issued. The LPSC staff commented that the proposed rule would likely set forth a generic mechanism that can be used by utilities to reflect the effects of the Tax Act in rates and a process by which utilities can propose utility specific treatment, if desired. See the “Formula Rate Plan Extension Request” discussion below. In the formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana will return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the parties agreed that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana would establish a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month until new base rates under the formula rate plan are established, and this regulatory liability will be returned to customers over the next formula rate plan rate-effective period. Entergy Louisiana recorded a $27 million regulatory liability in the first quarter 2018 pursuant to this provision of the settlement. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and analysis thereof as part of the formula rate plan review proceeding for the upcoming 2017 test year filing. Entergy Mississippi As discussed in the Form 10-K, after enactment of the Tax Act the MPSC ordered utilities, including Entergy Mississippi, that operate under a formula rate plan to file a description by February 26, 2018, of how the Tax Act will be reflected in the formula rate plan under which the utility operates. Entergy Mississippi's plan, as filed with the MPSC on February 26, 2018, included a request to reflect the changes related to the Tax Act in the 2018 formula rate plan filing. Entergy Mississippi filed its 2018 formula rate plan on March 15, 2018 and included a proposal to return all of its unprotected excess accumulated deferred income taxes to customers through rates or in exchange for other assets, or a combination of both, by the end of 2018. Also, in March 2018 the MPSC issued a subsequent order in its generic tax reform docket ordering utilities, including Entergy Mississippi, to explain the implementation of the utilities tax adjustment clause, or, in the alternative, why the tax adjustment clause is inapplicable; submit an analysis of the ratemaking effects of the Tax Act on current and future revenue requirements for rate schedules that include a gross-up for federal taxes; and make appropriate accounting entries to recognize the removal of excess deferred taxes from the balance of the utility’s accumulated deferred income tax account, or, in the alternative, explain why recording such entries is not appropriate. In April 2018, Entergy Mississippi filed its response to the MPSC stating that the tax adjustment clauses in its base rates are properly implemented through its formula rate plan. Entergy Mississippi also provided analysis of the ratemaking effects of the Tax Act. Entergy New Orleans As discussed in the Form 10-K, after enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. In March 2018, Entergy New Orleans filed its response to that resolution stating that the Tax Act reduced income tax expense from what is presently reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy has submitted filings of this type to the FERC. System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposes to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2018, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01547 per kWh to $0.01882 per kWh. The Arkansas Attorney General filed a response to Entergy Arkansas’s annual redetermination filing requesting that the APSC suspend the proposed tariff to investigate the amount of the redetermination or, alternatively, to allow recovery subject to refund. Among the reasons the Arkansas Attorney General cited for suspension were questions pertaining to how Entergy Arkansas forecasted sales and potential implications of the Tax Act. Entergy Arkansas replied to the Arkansas Attorney General’s filing and stated that, to the extent there are questions pertaining to its load forecasting or the operation of the energy cost recovery rider, those issues exceed the scope of the instant rate redetermination. Entergy Arkansas also stated that potential effects of the Tax Act are appropriately considered in the APSC’s separate proceeding looking at potential implications of the new tax law. The APSC general staff filed a reply to the Arkansas Attorney General’s filing and agreed that Entergy Arkansas’s filing complied with the terms of the energy cost recovery rider. In April 2018 the APSC issued an order declining to suspend Entergy Arkansas’s energy cost recovery rider rate and declining to require further investigation of the issues suggested by the Attorney General in the proceeding at this time. The redetermined rate became effective with the first billing cycle of April 2018. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in an open PUCT proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. The pending appeals did not stay the PUCT’s decision, and Entergy Texas refunded to customers the $10.9 million over a four-month period beginning with the first billing cycle of July 2016. The federal appeal of the PUCT’s January 2016 decision was heard in December 2016, and the Federal District Court granted Entergy Texas’s requested relief. In January 2017 the PUCT and an intervenor filed petitions for appeal to the U.S. Court of Appeals for the Fifth Circuit of the Federal District Court ruling. Oral argument was held before the U.S. Court of Appeals for the Fifth Circuit in February 2018. In April 2018 the U.S. Court of Appeals for the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. Entergy Texas is considering its legal options. The State District Court appeal of the PUCT’s January 2016 decision remains pending. In December 2017, Entergy Texas filed an application for a fuel refund of approximately $30.5 million for the months of May 2017 through October 2017. Also in December 2017, the PUCT’s ALJ approved the refund on an interim basis. For most customers, the refunds flowed through bills beginning January 2018 and continued through March 2018. The fuel refund was approved by the PUCT in March 2018. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC (Entergy Arkansas) Internal Restructuring As discussed in the Form 10-K, in November 2017, Entergy Arkansas filed an application with the APSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Arkansas to a new entity, which would ultimately be owned by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval by the APSC, the FERC, and the NRC. Entergy Arkansas also filed a notice with the Missouri Public Service Commission in December 2017 out of an abundance of caution, although Entergy Arkansas does not serve any retail customers in Missouri. In April 2018 the Missouri Public Service Commission approved Entergy Arkansas’s filing. If the appropriate approvals are obtained, Entergy Arkansas expects the restructuring will be consummated on or before December 1, 2018. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric Formula Rate Plan Extension Request In August 2017, Entergy Louisiana filed a request with the LPSC seeking to extend its formula rate plan for three years (2017-2019) with limited modifications of its terms. Those modifications include: a one-time resetting of base rates to the midpoint of the band at Entergy Louisiana’s authorized return on equity of 9.95% for the 2017 test year; narrowing of the formula rate plan bandwidth from a total of 160 basis points to 80 basis points; and a forward-looking mechanism that would allow Entergy Louisiana to recover certain transmission-related costs contemporaneously with when those projects begin delivering benefits to customers. Several parties intervened in the proceeding and all parties participated in settlement discussions. In April 2018 the LPSC approved an unopposed joint motion filed by Entergy Louisiana and the LPSC staff that settles the matter. The settlement extends the formula rate plan for three years, providing for rates through at least August 2021. In addition to retaining the major features of the traditional formula rate plan, substantive features of the extended formula rate plan include: • a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation; • a 9.8% target earned return on common equity for the 2018 and 2019 test years; • narrowing of the common equity bandwidth to plus or minus 60 basis points around the earned return on common equity; • a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity); • a framework for the flow back of certain tax benefits created by the Tax Act to customers, as described in “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above; and • a transmission recovery mechanism providing for the opportunity to recover certain transmission related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism. Union Power Station and Deactivation or Retirement Decisions for Entergy Louisiana Plants As discussed in the Form 10-K, as a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three-year term permitted by MISO. In March 2018 the LPSC adopted the ALJ’s recommended order finding that Entergy Louisiana did not demonstrate that its decision to permanently surrender transmission rights for the mothballed (not retired) Willow Glen 2 and 4 units was reasonable and that Entergy Louisiana should hold customers harmless from increased transmission expenses should those units be reactivated. Because no party or the LPSC suggested that Willow Glen 2 and 4 should be reactivated and because the cost to return those units to service far exceeds the revenue the units were expected to generate in MISO, Entergy Louisiana retired Willow Glen 2 and 4 in March 2018. Retail Rates - Gas 2017 Rate Stabilization Plan Filing In January 2018, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. The filing of the evaluation report for the test year 2017 reflected an earned return on common equity of 9.06% . This earned return is below the earnings sharing band of the rate stabilization plan and results in a rate increase of $0.1 million . Due to the enactment of the Tax Act in late-December 2017, Entergy Louisiana did not have adequate time to reflect the effects of this tax legislation in the rate stabilization plan. In April 2018 Entergy Louisiana filed a supplemental evaluation report for the test year ended September 2017, reflecting the effects of the Tax Act, including a proposal to use the unprotected excess accumulated deferred income taxes to offset storm restoration deferred operation and maintenance costs incurred by Entergy Louisiana in connection with the August 2016 flooding disaster in its gas service area. The supplemental filing reflects an earned return on common equity of 10.79% . If the as-filed rates from the supplemental filing are accepted by the LPSC, customers will receive a cost reduction of approximately $0.7 million effective with bills rendered on and after the first billing cycle of May 2018, as well as a $0.2 million prospective reduction in the gas infrastructure rider effective with bills rendered on and after the first billing cycle of July 2018. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2018, Entergy Mississippi submitted its formula rate plan 2018 test year filing and 2017 look-back filing showing Entergy Mississippi’s earned return for the historical 2017 calendar year and projected earned return for the 2018 calendar year, in large part as a result of the lower federal corporate income tax rate effective in 2018, to be within the formula rate plan bandwidth, resulting in no change in rates. The filing is currently subject to MPSC review. See “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above for additional discussion regarding the proposed treatment of the effects of the lower federal corporate income tax rate. Internal Restructuring In March 2018, Entergy Mississippi filed an application with the MPSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Mississippi to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval by the MPSC, the FERC, and the NRC. If the MPSC approves the restructuring by August 2018 and the restructuring closes on or before December 1, 2018, Entergy Mississippi proposed in its application to credit retail customers $27 million over six years, beginning in 2019. If the MPSC, the FERC, and the NRC approvals are obtained, Entergy Mississippi expects the restructuring will be consummated on or before December 1, 2018. It is currently contemplated that Entergy Mississippi would undertake a multi-step restructuring, which would include the following: • Entergy Mississippi would redeem its outstanding preferred stock, at the aggregate redemption price of approximately $21.2 million , including call premiums, plus accumulated and unpaid dividends, if any. • Entergy Mississippi would convert from a Mississippi corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy Mississippi will allocate substantially all of its assets to a new subsidiary, Entergy Mississippi Power and Light, LLC, a Texas limited liability company (Entergy Mississippi Power and Light), and Entergy Mississippi Power and Light will assume substantially all of the liabilities of Entergy Mississippi, in a transaction regarded as a merger under the TXBOC. Entergy Mississippi will remain in existence and hold the membership interests in Entergy Mississippi Power and Light. • Entergy Mississippi will contribute the membership interests in Entergy Mississippi Power and Light to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy Mississippi Power and Light will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC. • Entergy Mississippi will change its name to Entergy Utility Enterprises, Inc., and Entergy Mississippi Power and Light will then change its name to Entergy Mississippi, LLC. Upon the completion of the restructuring, Entergy Mississippi, LLC will hold substantially all of the assets, and will have assumed substantially all of the liabilities, of Entergy Mississippi. Entergy Mississippi may modify or supplement the steps to be taken to effectuate the restructuring. Advanced Metering Infrastructure (AMI) Filings Entergy New Orleans As discussed in the Form 10-K, in February 2018 the City Council approved Entergy New Orleans’s application seeking a finding that Entergy New Orleans’s deployment of advanced electric and gas metering infrastructure is in the public interest. Deployment of the information technology infrastructure began in 2017 and deployment of the communications network is expected to begin later in 2018. In April 2018 the City Council adopted a resolution directing Entergy New Orleans to explore the options for accelerating the deployment of AMI. Entergy New Orleans is required to report its findings to the City Council by June 2018. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, in August 2017 the D.C. Circuit issued a decision denying the LPSC’s appeal of the FERC’s October 2011 and February 2014 orders, but also granting the request by all parties to the appeal for remand and agency reconsideration on the issue of whether the operating companies should be required to issue refunds for the 20-month period from September 2001 to May 2003. The matter was remanded back to the FERC and, in March 2018, the LPSC filed at the FERC its initial brief addressing the issue that the D.C. Circuit remanded back to the FERC in August 2017. In its brief, the LPSC argued that the FERC should require the Utility operating companies to issue refunds for the 20-month refund period from September 2001 to May 2003. Rough Production Cost Equalization Rates Consolidated 2011, 2012, 2013, and 2014 Rate Filing Proceedings As discussed in the Form 10-K, in December 2014 the FERC consolidated the 2011, 2012, 2013, and 2014 rate filings for settlement and hearing procedures. In May 2015, Entergy filed direct testimony in the consolidated rate filings and the LPSC filed direct testimony concerning its complaint proceeding that is consolidated with the rate filings, challenging certain components of the pending bandwidth calculations for prior years. Hearings occurred in November 2015, and the ALJ issued an initial decision in July 2016. In the initial decision, the ALJ generally agreed with Entergy’s bandwidth calculations with one exception on the accounting related to the Waterford 3 sale/leaseback. In March 2018 the FERC issued an order affirming the initial decision. In April 2018 the LPSC requested rehearing of the FERC’s March 2018 order affirming the ALJ’s initial decision. Based on the March 2018 FERC order, the following preliminary estimated payments/receipts were recorded in March 2018 among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $6 Entergy New Orleans $2 Entergy Texas ($8) Entergy Services expects to file in May 2018 the bandwidth true-up payments and receipts for the 2011-2014 rate filings. Interruptible Load Proceedings See the Form 10-K for a discussion of the interruptible load proceedings. As discussed in the Form 10-K, the LPSC appealed the April and September 2016 orders to the D.C. Circuit. In March 2018 the D.C. Circuit issued an order denying the LPSC’s appeal and affirming the FERC’s decision that it would be inequitable to award refunds in the proceeding. In April 2018 the LPSC sought rehearing en banc of the D.C. Circuit’s order denying the LPSC’s appeal. Complaint Against System Energy As discussed in the Form 10-K, in January 2017 the APSC and the MPSC filed a complaint requesting that the FERC establish proceedings to investigate System Energy’s return on equity under the Unit Power Sales Agreement, establish a refund effective date, and establish a new and lower return on equity. In September 2017 the FERC established a refund effective date of January 23, 2017, consolidated the return on equity complaint with the proceeding described in “ Unit Power Sales Agreement ” in the Form 10-K, and directed the parties to engage in settlement proceedings before an ALJ. Settlement discussions are ongoing. The refund effective date in connection with the APSC/MPSC complaint expired on April 23, 2018. In April 2018 the LPSC filed a complaint with the FERC against System Energy seeking an additional fifteen-month refund period. The LPSC complaint requests similar relief from the FERC with respect to System Energy’s return on equity and also requests the FERC to investigate System Energy’s capital structure and application of System Energy’s allowed depreciation rates to plant additions associated with the Grand Gulf sale/leaseback transactions. System Energy expects to answer the LPSC complaint in May 2018.
System Energy [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements in the Form 10-K for discussion of the effects of the enactment in December 2017 of the Tax Cuts and Jobs Act (the Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. After assessing the activity described in more detail below regarding the proposals the Registrant Subsidiaries have made to their regulators for the return of unprotected excess accumulated deferred income taxes to customers, in the first quarter 2018, Entergy and each of the Registrant Subsidiaries reclassified from the regulatory liability for income taxes to current liabilities the portion of their unprotected excess accumulated deferred income taxes that they expect to return to customers over the next twelve months. Entergy Arkansas See the Form 10-K for a discussion of the activity of the APSC and Entergy Arkansas after enactment of the Tax Act in December 2017. The APSC granted Entergy Arkansas’s request for clarification regarding the APSC’s order issued after enactment of the Tax Act. The APSC states that its order was not a final determination and that the APSC has made no decision at this time on the appropriate final accounting or ratemaking treatment of the amounts in question. Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff docket in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits associated with the Tax Act. For the residential customer class, the unprotected excess accumulated deferred income taxes will be returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, the unprotected excess accumulated deferred income taxes will be returned to customers over a 9-month period from April 2018 through December 2018. A true-up provision also was included, with any over- or under-returned unprotected excess accumulated deferred income taxes to be credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. Entergy Louisiana See the Form 10-K for a discussion of the activity of the LPSC and Entergy Louisiana after enactment of the Tax Act in December 2017. At the March 2018 LPSC Business and Executive Session, the LPSC staff provided a report on the tax-related rulemaking and invited additional interventions and comments before a proposed rule is issued. The LPSC staff commented that the proposed rule would likely set forth a generic mechanism that can be used by utilities to reflect the effects of the Tax Act in rates and a process by which utilities can propose utility specific treatment, if desired. See the “Formula Rate Plan Extension Request” discussion below. In the formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana will return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the parties agreed that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana would establish a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month until new base rates under the formula rate plan are established, and this regulatory liability will be returned to customers over the next formula rate plan rate-effective period. Entergy Louisiana recorded a $27 million regulatory liability in the first quarter 2018 pursuant to this provision of the settlement. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and analysis thereof as part of the formula rate plan review proceeding for the upcoming 2017 test year filing. Entergy Mississippi As discussed in the Form 10-K, after enactment of the Tax Act the MPSC ordered utilities, including Entergy Mississippi, that operate under a formula rate plan to file a description by February 26, 2018, of how the Tax Act will be reflected in the formula rate plan under which the utility operates. Entergy Mississippi's plan, as filed with the MPSC on February 26, 2018, included a request to reflect the changes related to the Tax Act in the 2018 formula rate plan filing. Entergy Mississippi filed its 2018 formula rate plan on March 15, 2018 and included a proposal to return all of its unprotected excess accumulated deferred income taxes to customers through rates or in exchange for other assets, or a combination of both, by the end of 2018. Also, in March 2018 the MPSC issued a subsequent order in its generic tax reform docket ordering utilities, including Entergy Mississippi, to explain the implementation of the utilities tax adjustment clause, or, in the alternative, why the tax adjustment clause is inapplicable; submit an analysis of the ratemaking effects of the Tax Act on current and future revenue requirements for rate schedules that include a gross-up for federal taxes; and make appropriate accounting entries to recognize the removal of excess deferred taxes from the balance of the utility’s accumulated deferred income tax account, or, in the alternative, explain why recording such entries is not appropriate. In April 2018, Entergy Mississippi filed its response to the MPSC stating that the tax adjustment clauses in its base rates are properly implemented through its formula rate plan. Entergy Mississippi also provided analysis of the ratemaking effects of the Tax Act. Entergy New Orleans As discussed in the Form 10-K, after enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. In March 2018, Entergy New Orleans filed its response to that resolution stating that the Tax Act reduced income tax expense from what is presently reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy has submitted filings of this type to the FERC. System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposes to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2018, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.01547 per kWh to $0.01882 per kWh. The Arkansas Attorney General filed a response to Entergy Arkansas’s annual redetermination filing requesting that the APSC suspend the proposed tariff to investigate the amount of the redetermination or, alternatively, to allow recovery subject to refund. Among the reasons the Arkansas Attorney General cited for suspension were questions pertaining to how Entergy Arkansas forecasted sales and potential implications of the Tax Act. Entergy Arkansas replied to the Arkansas Attorney General’s filing and stated that, to the extent there are questions pertaining to its load forecasting or the operation of the energy cost recovery rider, those issues exceed the scope of the instant rate redetermination. Entergy Arkansas also stated that potential effects of the Tax Act are appropriately considered in the APSC’s separate proceeding looking at potential implications of the new tax law. The APSC general staff filed a reply to the Arkansas Attorney General’s filing and agreed that Entergy Arkansas’s filing complied with the terms of the energy cost recovery rider. In April 2018 the APSC issued an order declining to suspend Entergy Arkansas’s energy cost recovery rider rate and declining to require further investigation of the issues suggested by the Attorney General in the proceeding at this time. The redetermined rate became effective with the first billing cycle of April 2018. Entergy Texas As discussed in the Form 10-K, in July 2015 certain parties filed briefs in an open PUCT proceeding asserting that Entergy Texas should refund to retail customers an additional $10.9 million in bandwidth remedy payments Entergy Texas received related to calendar year 2006 production costs. In October 2015 an ALJ issued a proposal for decision recommending that the additional bandwidth remedy payments be refunded to retail customers. In January 2016 the PUCT issued its order affirming the ALJ’s recommendation, and Entergy Texas filed a motion for rehearing of the PUCT’s decision, which the PUCT denied. In March 2016, Entergy Texas filed a complaint in Federal District Court for the Western District of Texas and a petition in the Travis County (State) District Court appealing the PUCT’s decision. The pending appeals did not stay the PUCT’s decision, and Entergy Texas refunded to customers the $10.9 million over a four-month period beginning with the first billing cycle of July 2016. The federal appeal of the PUCT’s January 2016 decision was heard in December 2016, and the Federal District Court granted Entergy Texas’s requested relief. In January 2017 the PUCT and an intervenor filed petitions for appeal to the U.S. Court of Appeals for the Fifth Circuit of the Federal District Court ruling. Oral argument was held before the U.S. Court of Appeals for the Fifth Circuit in February 2018. In April 2018 the U.S. Court of Appeals for the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. Entergy Texas is considering its legal options. The State District Court appeal of the PUCT’s January 2016 decision remains pending. In December 2017, Entergy Texas filed an application for a fuel refund of approximately $30.5 million for the months of May 2017 through October 2017. Also in December 2017, the PUCT’s ALJ approved the refund on an interim basis. For most customers, the refunds flowed through bills beginning January 2018 and continued through March 2018. The fuel refund was approved by the PUCT in March 2018. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for detailed information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information. Filings with the APSC (Entergy Arkansas) Internal Restructuring As discussed in the Form 10-K, in November 2017, Entergy Arkansas filed an application with the APSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Arkansas to a new entity, which would ultimately be owned by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval by the APSC, the FERC, and the NRC. Entergy Arkansas also filed a notice with the Missouri Public Service Commission in December 2017 out of an abundance of caution, although Entergy Arkansas does not serve any retail customers in Missouri. In April 2018 the Missouri Public Service Commission approved Entergy Arkansas’s filing. If the appropriate approvals are obtained, Entergy Arkansas expects the restructuring will be consummated on or before December 1, 2018. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric Formula Rate Plan Extension Request In August 2017, Entergy Louisiana filed a request with the LPSC seeking to extend its formula rate plan for three years (2017-2019) with limited modifications of its terms. Those modifications include: a one-time resetting of base rates to the midpoint of the band at Entergy Louisiana’s authorized return on equity of 9.95% for the 2017 test year; narrowing of the formula rate plan bandwidth from a total of 160 basis points to 80 basis points; and a forward-looking mechanism that would allow Entergy Louisiana to recover certain transmission-related costs contemporaneously with when those projects begin delivering benefits to customers. Several parties intervened in the proceeding and all parties participated in settlement discussions. In April 2018 the LPSC approved an unopposed joint motion filed by Entergy Louisiana and the LPSC staff that settles the matter. The settlement extends the formula rate plan for three years, providing for rates through at least August 2021. In addition to retaining the major features of the traditional formula rate plan, substantive features of the extended formula rate plan include: • a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation; • a 9.8% target earned return on common equity for the 2018 and 2019 test years; • narrowing of the common equity bandwidth to plus or minus 60 basis points around the earned return on common equity; • a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity); • a framework for the flow back of certain tax benefits created by the Tax Act to customers, as described in “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above; and • a transmission recovery mechanism providing for the opportunity to recover certain transmission related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism. Union Power Station and Deactivation or Retirement Decisions for Entergy Louisiana Plants As discussed in the Form 10-K, as a term of the LPSC-approved settlement authorizing the purchase of Power Blocks 3 and 4 of the Union Power Station, Entergy Louisiana agreed to make a filing with the LPSC to review its decisions to deactivate Ninemile 3 and Willow Glen 2 and 4 and its decision to retire Little Gypsy 1. In January 2016, Entergy Louisiana made its compliance filing with the LPSC. Entergy Louisiana, LPSC staff, and intervenors participated in a technical conference in March 2016 where Entergy Louisiana presented information on its deactivation/retirement decisions for these four units in addition to information on the current deactivation decisions for the ten-year planning horizon. No party contests the prudence of the decision to deactivate Willow Glen 2 and 4 or suggests reactivation of these units; however, issues have been raised related to Entergy Louisiana’s decision to give up its transmission service rights in MISO for Willow Glen 2 and 4 rather than placing the units into suspended status for the three-year term permitted by MISO. In March 2018 the LPSC adopted the ALJ’s recommended order finding that Entergy Louisiana did not demonstrate that its decision to permanently surrender transmission rights for the mothballed (not retired) Willow Glen 2 and 4 units was reasonable and that Entergy Louisiana should hold customers harmless from increased transmission expenses should those units be reactivated. Because no party or the LPSC suggested that Willow Glen 2 and 4 should be reactivated and because the cost to return those units to service far exceeds the revenue the units were expected to generate in MISO, Entergy Louisiana retired Willow Glen 2 and 4 in March 2018. Retail Rates - Gas 2017 Rate Stabilization Plan Filing In January 2018, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2017. The filing of the evaluation report for the test year 2017 reflected an earned return on common equity of 9.06% . This earned return is below the earnings sharing band of the rate stabilization plan and results in a rate increase of $0.1 million . Due to the enactment of the Tax Act in late-December 2017, Entergy Louisiana did not have adequate time to reflect the effects of this tax legislation in the rate stabilization plan. In April 2018 Entergy Louisiana filed a supplemental evaluation report for the test year ended September 2017, reflecting the effects of the Tax Act, including a proposal to use the unprotected excess accumulated deferred income taxes to offset storm restoration deferred operation and maintenance costs incurred by Entergy Louisiana in connection with the August 2016 flooding disaster in its gas service area. The supplemental filing reflects an earned return on common equity of 10.79% . If the as-filed rates from the supplemental filing are accepted by the LPSC, customers will receive a cost reduction of approximately $0.7 million effective with bills rendered on and after the first billing cycle of May 2018, as well as a $0.2 million prospective reduction in the gas infrastructure rider effective with bills rendered on and after the first billing cycle of July 2018. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2018, Entergy Mississippi submitted its formula rate plan 2018 test year filing and 2017 look-back filing showing Entergy Mississippi’s earned return for the historical 2017 calendar year and projected earned return for the 2018 calendar year, in large part as a result of the lower federal corporate income tax rate effective in 2018, to be within the formula rate plan bandwidth, resulting in no change in rates. The filing is currently subject to MPSC review. See “ Regulatory activity regarding the Tax Cuts and Jobs Act ” above for additional discussion regarding the proposed treatment of the effects of the lower federal corporate income tax rate. Internal Restructuring In March 2018, Entergy Mississippi filed an application with the MPSC seeking authorization to undertake a restructuring that would result in the transfer of substantially all of the assets and operations of Entergy Mississippi to a new entity, which would ultimately be held by an existing Entergy subsidiary holding company. The restructuring is subject to regulatory review and approval by the MPSC, the FERC, and the NRC. If the MPSC approves the restructuring by August 2018 and the restructuring closes on or before December 1, 2018, Entergy Mississippi proposed in its application to credit retail customers $27 million over six years, beginning in 2019. If the MPSC, the FERC, and the NRC approvals are obtained, Entergy Mississippi expects the restructuring will be consummated on or before December 1, 2018. It is currently contemplated that Entergy Mississippi would undertake a multi-step restructuring, which would include the following: • Entergy Mississippi would redeem its outstanding preferred stock, at the aggregate redemption price of approximately $21.2 million , including call premiums, plus accumulated and unpaid dividends, if any. • Entergy Mississippi would convert from a Mississippi corporation to a Texas corporation. • Under the Texas Business Organizations Code (TXBOC), Entergy Mississippi will allocate substantially all of its assets to a new subsidiary, Entergy Mississippi Power and Light, LLC, a Texas limited liability company (Entergy Mississippi Power and Light), and Entergy Mississippi Power and Light will assume substantially all of the liabilities of Entergy Mississippi, in a transaction regarded as a merger under the TXBOC. Entergy Mississippi will remain in existence and hold the membership interests in Entergy Mississippi Power and Light. • Entergy Mississippi will contribute the membership interests in Entergy Mississippi Power and Light to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy Mississippi Power and Light will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC. • Entergy Mississippi will change its name to Entergy Utility Enterprises, Inc., and Entergy Mississippi Power and Light will then change its name to Entergy Mississippi, LLC. Upon the completion of the restructuring, Entergy Mississippi, LLC will hold substantially all of the assets, and will have assumed substantially all of the liabilities, of Entergy Mississippi. Entergy Mississippi may modify or supplement the steps to be taken to effectuate the restructuring. Advanced Metering Infrastructure (AMI) Filings Entergy New Orleans As discussed in the Form 10-K, in February 2018 the City Council approved Entergy New Orleans’s application seeking a finding that Entergy New Orleans’s deployment of advanced electric and gas metering infrastructure is in the public interest. Deployment of the information technology infrastructure began in 2017 and deployment of the communications network is expected to begin later in 2018. In April 2018 the City Council adopted a resolution directing Entergy New Orleans to explore the options for accelerating the deployment of AMI. Entergy New Orleans is required to report its findings to the City Council by June 2018. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, in August 2017 the D.C. Circuit issued a decision denying the LPSC’s appeal of the FERC’s October 2011 and February 2014 orders, but also granting the request by all parties to the appeal for remand and agency reconsideration on the issue of whether the operating companies should be required to issue refunds for the 20-month period from September 2001 to May 2003. The matter was remanded back to the FERC and, in March 2018, the LPSC filed at the FERC its initial brief addressing the issue that the D.C. Circuit remanded back to the FERC in August 2017. In its brief, the LPSC argued that the FERC should require the Utility operating companies to issue refunds for the 20-month refund period from September 2001 to May 2003. Rough Production Cost Equalization Rates Consolidated 2011, 2012, 2013, and 2014 Rate Filing Proceedings As discussed in the Form 10-K, in December 2014 the FERC consolidated the 2011, 2012, 2013, and 2014 rate filings for settlement and hearing procedures. In May 2015, Entergy filed direct testimony in the consolidated rate filings and the LPSC filed direct testimony concerning its complaint proceeding that is consolidated with the rate filings, challenging certain components of the pending bandwidth calculations for prior years. Hearings occurred in November 2015, and the ALJ issued an initial decision in July 2016. In the initial decision, the ALJ generally agreed with Entergy’s bandwidth calculations with one exception on the accounting related to the Waterford 3 sale/leaseback. In March 2018 the FERC issued an order affirming the initial decision. In April 2018 the LPSC requested rehearing of the FERC’s March 2018 order affirming the ALJ’s initial decision. Based on the March 2018 FERC order, the following preliminary estimated payments/receipts were recorded in March 2018 among the Utility operating companies: Payments (Receipts) (In Millions) Entergy Arkansas $6 Entergy New Orleans $2 Entergy Texas ($8) Entergy Services expects to file in May 2018 the bandwidth true-up payments and receipts for the 2011-2014 rate filings. Interruptible Load Proceedings See the Form 10-K for a discussion of the interruptible load proceedings. As discussed in the Form 10-K, the LPSC appealed the April and September 2016 orders to the D.C. Circuit. In March 2018 the D.C. Circuit issued an order denying the LPSC’s appeal and affirming the FERC’s decision that it would be inequitable to award refunds in the proceeding. In April 2018 the LPSC sought rehearing en banc of the D.C. Circuit’s order denying the LPSC’s appeal. Complaint Against System Energy As discussed in the Form 10-K, in January 2017 the APSC and the MPSC filed a complaint requesting that the FERC establish proceedings to investigate System Energy’s return on equity under the Unit Power Sales Agreement, establish a refund effective date, and establish a new and lower return on equity. In September 2017 the FERC established a refund effective date of January 23, 2017, consolidated the return on equity complaint with the proceeding described in “ Unit Power Sales Agreement ” in the Form 10-K, and directed the parties to engage in settlement proceedings before an ALJ. Settlement discussions are ongoing. The refund effective date in connection with the APSC/MPSC complaint expired on April 23, 2018. In April 2018 the LPSC filed a complaint with the FERC against System Energy seeking an additional fifteen-month refund period. The LPSC complaint requests similar relief from the FERC with respect to System Energy’s return on equity and also requests the FERC to investigate System Energy’s capital structure and application of System Energy’s allowed depreciation rates to plant additions associated with the Grand Gulf sale/leaseback transactions. System Energy expects to answer the LPSC complaint in May 2018.

Equity

Equity	3 Months Ended
	Mar. 31, 2018
Equity	EQUITY (Entergy Corporation and Entergy Louisiana) Common Stock Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Three Months Ended March 31, 2018 2017 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $132.8 180.7 $0.73 $82.6 179.3 $0.46 Average dilutive effect of: Stock options 0.2 — 0.1 — Other equity plans 0.5 — 0.4 — Diluted earnings per share $132.8 181.4 $0.73 $82.6 179.8 $0.46 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 4 million for the three months ended March 31, 2018 and approximately 4.9 million for the three months ended March 31, 2017 . Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K. Treasury Stock During the three months ended March 31, 2018 , Entergy Corporation issued 281,614 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards. Entergy Corporation did not repurchase any of its common stock during the three months ended March 31, 2018 . Retained Earnings On April 11, 2018, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.89 per share, payable on June 1, 2018, to holders of record as of May 10, 2018. Entergy implemented ASU No. 2016-01 “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” effective January 1, 2018. The ASU requires investments in equity securities, excluding those accounted for under the equity method or resulting in consolidation of the investee, to be measured at fair value with changes recognized in net income. Entergy implemented this standard using a modified retrospective method, and recorded an adjustment increasing retained earnings and reducing accumulated other comprehensive income by $633 million as of January 1, 2018 for the cumulative effect of the unrealized gains and losses on investments in equity securities held by the decommissioning trust funds that do not meet the criteria for regulatory accounting treatment. See Note 9 to the financial statements herein for further discussion of effects of the new standard. Entergy implemented ASU No. 2016-16, “Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory” effective January 1, 2018. The ASU requires entities to recognize the income tax consequences of intra-entity asset transfers, other than inventory, at the time the transfer occurs. Entergy implemented this standard using a modified retrospective method, and recorded an adjustment decreasing retained earnings by $56 million as of January 1, 2018 for the cumulative effect of recording deferred tax assets on previously-recognized intra-entity asset transfers. Entergy adopted ASU No. 2018-02, “Income Statement - Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income,” in the first quarter 2018. The ASU allows a one-time reclassification from accumulated other comprehensive income to retained earnings for certain tax effects resulting from the Tax Cuts and Jobs Act that would otherwise be stranded in accumulated other comprehensive income. Entergy’s policy for releasing income tax effects from accumulated other comprehensive income for available-for-sale securities is to use the portfolio approach. Entergy elected to reclassify the $15.5 million of stranded tax effects in accumulated other comprehensive income resulting from the Tax Cuts and Jobs Act to retained earnings ( $32 million decrease) or the regulatory liability for income taxes ( $16.5 million increase). Entergy’s reclassification only includes the effect of the change in the federal corporate income tax rate on accumulated other comprehensive income. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Ending balance, December 31, 2017 ($37,477 ) ($531,099 ) $545,045 ($23,531 ) Implementation of accounting standards — — (632,617 ) (632,617 ) Beginning balance, January 1, 2018 ($37,477 ) ($531,099 ) ($87,572 ) ($656,148 ) Other comprehensive income (loss) before reclassifications 71,566 — 838 72,404 Amounts reclassified from accumulated other comprehensive income (loss) 23,861 16,574 (33,694 ) 6,741 Net other comprehensive income (loss) for the period 95,427 16,574 (32,856 ) 79,145 Reclassification pursuant to ASU 2018-02 (7,756 ) (90,966 ) 114,227 15,505 Ending balance, March 31, 2018 $50,194 ($605,491 ) ($6,201 ) ($561,498 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 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 32,608 — 39,872 — 72,480 Amounts reclassified from accumulated other comprehensive income (loss) (33,136 ) 8,632 (2,045 ) — (26,549 ) Net other comprehensive income (loss) for the period (528 ) 8,632 37,827 — 45,931 Ending balance, March 31, 2017 $3,465 ($460,814 ) $467,561 $748 $10,960 The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended March 31, 2018 and 2017: Pension and Other 2018 2017 (In Thousands) Beginning balance, January 1, ($46,400 ) ($48,442 ) Amounts reclassified from accumulated other (501 ) (370 ) Net other comprehensive income (loss) for the period (501 ) (370 ) Reclassification pursuant to ASU 2018-02 (10,049 ) — Ending balance, March 31, ($56,950 ) ($48,812 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended March 31, 2018 and 2017 are as follows: Amounts reclassified Income Statement Location 2018 2017 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts ($30,082 ) $51,227 Competitive business operating revenues Interest rate swaps (122 ) (250 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges (30,204 ) 50,977 6,343 (17,841 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) ($23,861 ) $33,136 Pension and other postretirement liabilities Amortization of prior-service credit $5,426 $6,562 (a) Amortization of loss (24,952 ) (21,571 ) (a) Settlement loss (1,616 ) — (a) Total amortization (21,142 ) (15,009 ) 4,568 6,377 Income taxes Total amortization (net of tax) ($16,574 ) ($8,632 ) Net unrealized investment gain (loss) Realized gain (loss) $53,314 $4,010 Interest and investment income (19,620 ) (1,965 ) Income taxes Total realized investment gain (loss) (net of tax) $33,694 $2,045 Total reclassifications for the period (net of tax) ($6,741 ) $26,549 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended March 31, 2018 and 2017 are as follows: Amounts reclassified Income Statement Location 2018 2017 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,934 $1,934 (a) Amortization of loss (1,257 ) (1,332 ) (a) Total amortization 677 602 (176 ) (232 ) Income taxes Total amortization (net of tax) 501 370 Total reclassifications for the period (net of tax) $501 $370 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.
Entergy Louisiana [Member]
Equity	EQUITY (Entergy Corporation and Entergy Louisiana) Common Stock Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Three Months Ended March 31, 2018 2017 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $132.8 180.7 $0.73 $82.6 179.3 $0.46 Average dilutive effect of: Stock options 0.2 — 0.1 — Other equity plans 0.5 — 0.4 — Diluted earnings per share $132.8 181.4 $0.73 $82.6 179.8 $0.46 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 4 million for the three months ended March 31, 2018 and approximately 4.9 million for the three months ended March 31, 2017 . Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K. Treasury Stock During the three months ended March 31, 2018 , Entergy Corporation issued 281,614 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards. Entergy Corporation did not repurchase any of its common stock during the three months ended March 31, 2018 . Retained Earnings On April 11, 2018, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.89 per share, payable on June 1, 2018, to holders of record as of May 10, 2018. Entergy implemented ASU No. 2016-01 “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” effective January 1, 2018. The ASU requires investments in equity securities, excluding those accounted for under the equity method or resulting in consolidation of the investee, to be measured at fair value with changes recognized in net income. Entergy implemented this standard using a modified retrospective method, and recorded an adjustment increasing retained earnings and reducing accumulated other comprehensive income by $633 million as of January 1, 2018 for the cumulative effect of the unrealized gains and losses on investments in equity securities held by the decommissioning trust funds that do not meet the criteria for regulatory accounting treatment. See Note 9 to the financial statements herein for further discussion of effects of the new standard. Entergy implemented ASU No. 2016-16, “Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory” effective January 1, 2018. The ASU requires entities to recognize the income tax consequences of intra-entity asset transfers, other than inventory, at the time the transfer occurs. Entergy implemented this standard using a modified retrospective method, and recorded an adjustment decreasing retained earnings by $56 million as of January 1, 2018 for the cumulative effect of recording deferred tax assets on previously-recognized intra-entity asset transfers. Entergy adopted ASU No. 2018-02, “Income Statement - Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income,” in the first quarter 2018. The ASU allows a one-time reclassification from accumulated other comprehensive income to retained earnings for certain tax effects resulting from the Tax Cuts and Jobs Act that would otherwise be stranded in accumulated other comprehensive income. Entergy’s policy for releasing income tax effects from accumulated other comprehensive income for available-for-sale securities is to use the portfolio approach. Entergy elected to reclassify the $15.5 million of stranded tax effects in accumulated other comprehensive income resulting from the Tax Cuts and Jobs Act to retained earnings ( $32 million decrease) or the regulatory liability for income taxes ( $16.5 million increase). Entergy’s reclassification only includes the effect of the change in the federal corporate income tax rate on accumulated other comprehensive income. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Ending balance, December 31, 2017 ($37,477 ) ($531,099 ) $545,045 ($23,531 ) Implementation of accounting standards — — (632,617 ) (632,617 ) Beginning balance, January 1, 2018 ($37,477 ) ($531,099 ) ($87,572 ) ($656,148 ) Other comprehensive income (loss) before reclassifications 71,566 — 838 72,404 Amounts reclassified from accumulated other comprehensive income (loss) 23,861 16,574 (33,694 ) 6,741 Net other comprehensive income (loss) for the period 95,427 16,574 (32,856 ) 79,145 Reclassification pursuant to ASU 2018-02 (7,756 ) (90,966 ) 114,227 15,505 Ending balance, March 31, 2018 $50,194 ($605,491 ) ($6,201 ) ($561,498 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 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 32,608 — 39,872 — 72,480 Amounts reclassified from accumulated other comprehensive income (loss) (33,136 ) 8,632 (2,045 ) — (26,549 ) Net other comprehensive income (loss) for the period (528 ) 8,632 37,827 — 45,931 Ending balance, March 31, 2017 $3,465 ($460,814 ) $467,561 $748 $10,960 The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended March 31, 2018 and 2017: Pension and Other 2018 2017 (In Thousands) Beginning balance, January 1, ($46,400 ) ($48,442 ) Amounts reclassified from accumulated other (501 ) (370 ) Net other comprehensive income (loss) for the period (501 ) (370 ) Reclassification pursuant to ASU 2018-02 (10,049 ) — Ending balance, March 31, ($56,950 ) ($48,812 ) Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended March 31, 2018 and 2017 are as follows: Amounts reclassified Income Statement Location 2018 2017 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts ($30,082 ) $51,227 Competitive business operating revenues Interest rate swaps (122 ) (250 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges (30,204 ) 50,977 6,343 (17,841 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) ($23,861 ) $33,136 Pension and other postretirement liabilities Amortization of prior-service credit $5,426 $6,562 (a) Amortization of loss (24,952 ) (21,571 ) (a) Settlement loss (1,616 ) — (a) Total amortization (21,142 ) (15,009 ) 4,568 6,377 Income taxes Total amortization (net of tax) ($16,574 ) ($8,632 ) Net unrealized investment gain (loss) Realized gain (loss) $53,314 $4,010 Interest and investment income (19,620 ) (1,965 ) Income taxes Total realized investment gain (loss) (net of tax) $33,694 $2,045 Total reclassifications for the period (net of tax) ($6,741 ) $26,549 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended March 31, 2018 and 2017 are as follows: Amounts reclassified Income Statement Location 2018 2017 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,934 $1,934 (a) Amortization of loss (1,257 ) (1,332 ) (a) Total amortization 677 602 (176 ) (232 ) Income taxes Total amortization (net of tax) 501 370 Total reclassifications for the period (net of tax) $501 $370 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.

Revolving Credit Facilities, Li

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	3 Months Ended
	Mar. 31, 2018
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in August 2022. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the three months ended March 31, 2018 was 3.31% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $1,125 $6 $2,369 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At March 31, 2018 , Entergy Corporation had $655 million of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2018 was 1.88% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2018 Letters of Credit Outstanding as of March 31, 2018 Entergy Arkansas April 2018 $20 million (b) 3.14% $— $— Entergy Arkansas August 2022 $150 million (c) 3.12% $50 million $— Entergy Louisiana August 2022 $350 million (c) 2.94% $100 million $9.1 million Entergy Mississippi May 2018 $37.5 million (d) 3.39% $— $— Entergy Mississippi May 2018 $35 million (d) 3.39% $— $— Entergy Mississippi May 2018 $20 million (d) 3.39% $— $— Entergy Mississippi May 2018 $10 million (d) 3.39% $— $— Entergy New Orleans November 2018 $25 million (c) 3.36% $— $0.8 million Entergy Texas August 2022 $150 million (c) 3.39% $— $24.4 million (a) For credit facilities with no borrowings as of March 31, 2018, the interest rate is the estimated interest rate as of March 31, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. In April 2018, Entergy Arkansas renewed its credit facility through April 2019. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. Entergy Mississippi expects to renew its credit facilities prior to expiration. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $23.8 million Entergy Mississippi $40 million 0.70% $16.6 million Entergy New Orleans $15 million 1.00% $4.8 million Entergy Texas $50 million 0.70% $25.6 million (a) As of March 31, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through October 31, 2019. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2018 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $124 Entergy Louisiana $450 $— Entergy Mississippi $175 $75 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facility Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $145 million that expires in November 2020. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of March 31, 2018 , $118 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the three months ended March 31, 2018 was 3.10% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of March 31, 2018 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 3.74% $43.9 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.82% $52.3 Entergy Louisiana Waterford VIE May 2019 $85 3.35% $62.9 (b) System Energy VIE May 2019 $120 3.46% $43.2 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) The total amount outstanding as of March 31, 2018 is commercial paper, and is classified as a current liability. 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 March 31, 2018 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million System Energy VIE 3.42% Series J due April 2021 $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Louisiana) In March 2018, Entergy Louisiana issued $750 million of 4.00% collateral trust mortgage bonds due March 2033. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and St. Charles Power Station; to repay, at maturity, its $375 million of 6.0% Series first mortgage bonds due May 2018; to repay borrowings from the money pool; to repay borrowings under its $350 million credit facility; and for general corporate purposes. (System Energy) In March 2018 the System Energy nuclear fuel trust variable interest entity issued $100 million of 3.42% Series J notes due April 2021. The System Energy nuclear fuel trust variable interest entity used the proceeds to purchase additional nuclear fuel. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,851,636 $16,771,585 Entergy Arkansas $2,978,569 $2,812,019 Entergy Louisiana $6,938,439 $7,022,323 Entergy Mississippi $1,270,399 $1,252,877 Entergy New Orleans $436,995 $446,981 Entergy Texas $1,562,555 $1,603,892 System Energy $601,582 $576,121 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $184 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Arkansas [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in August 2022. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the three months ended March 31, 2018 was 3.31% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $1,125 $6 $2,369 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At March 31, 2018 , Entergy Corporation had $655 million of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2018 was 1.88% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2018 Letters of Credit Outstanding as of March 31, 2018 Entergy Arkansas April 2018 $20 million (b) 3.14% $— $— Entergy Arkansas August 2022 $150 million (c) 3.12% $50 million $— Entergy Louisiana August 2022 $350 million (c) 2.94% $100 million $9.1 million Entergy Mississippi May 2018 $37.5 million (d) 3.39% $— $— Entergy Mississippi May 2018 $35 million (d) 3.39% $— $— Entergy Mississippi May 2018 $20 million (d) 3.39% $— $— Entergy Mississippi May 2018 $10 million (d) 3.39% $— $— Entergy New Orleans November 2018 $25 million (c) 3.36% $— $0.8 million Entergy Texas August 2022 $150 million (c) 3.39% $— $24.4 million (a) For credit facilities with no borrowings as of March 31, 2018, the interest rate is the estimated interest rate as of March 31, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. In April 2018, Entergy Arkansas renewed its credit facility through April 2019. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. Entergy Mississippi expects to renew its credit facilities prior to expiration. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $23.8 million Entergy Mississippi $40 million 0.70% $16.6 million Entergy New Orleans $15 million 1.00% $4.8 million Entergy Texas $50 million 0.70% $25.6 million (a) As of March 31, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through October 31, 2019. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2018 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $124 Entergy Louisiana $450 $— Entergy Mississippi $175 $75 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facility Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $145 million that expires in November 2020. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of March 31, 2018 , $118 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the three months ended March 31, 2018 was 3.10% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of March 31, 2018 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 3.74% $43.9 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.82% $52.3 Entergy Louisiana Waterford VIE May 2019 $85 3.35% $62.9 (b) System Energy VIE May 2019 $120 3.46% $43.2 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) The total amount outstanding as of March 31, 2018 is commercial paper, and is classified as a current liability. 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 March 31, 2018 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million System Energy VIE 3.42% Series J due April 2021 $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Louisiana) In March 2018, Entergy Louisiana issued $750 million of 4.00% collateral trust mortgage bonds due March 2033. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and St. Charles Power Station; to repay, at maturity, its $375 million of 6.0% Series first mortgage bonds due May 2018; to repay borrowings from the money pool; to repay borrowings under its $350 million credit facility; and for general corporate purposes. (System Energy) In March 2018 the System Energy nuclear fuel trust variable interest entity issued $100 million of 3.42% Series J notes due April 2021. The System Energy nuclear fuel trust variable interest entity used the proceeds to purchase additional nuclear fuel. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,851,636 $16,771,585 Entergy Arkansas $2,978,569 $2,812,019 Entergy Louisiana $6,938,439 $7,022,323 Entergy Mississippi $1,270,399 $1,252,877 Entergy New Orleans $436,995 $446,981 Entergy Texas $1,562,555 $1,603,892 System Energy $601,582 $576,121 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $184 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Louisiana [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in August 2022. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the three months ended March 31, 2018 was 3.31% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $1,125 $6 $2,369 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At March 31, 2018 , Entergy Corporation had $655 million of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2018 was 1.88% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2018 Letters of Credit Outstanding as of March 31, 2018 Entergy Arkansas April 2018 $20 million (b) 3.14% $— $— Entergy Arkansas August 2022 $150 million (c) 3.12% $50 million $— Entergy Louisiana August 2022 $350 million (c) 2.94% $100 million $9.1 million Entergy Mississippi May 2018 $37.5 million (d) 3.39% $— $— Entergy Mississippi May 2018 $35 million (d) 3.39% $— $— Entergy Mississippi May 2018 $20 million (d) 3.39% $— $— Entergy Mississippi May 2018 $10 million (d) 3.39% $— $— Entergy New Orleans November 2018 $25 million (c) 3.36% $— $0.8 million Entergy Texas August 2022 $150 million (c) 3.39% $— $24.4 million (a) For credit facilities with no borrowings as of March 31, 2018, the interest rate is the estimated interest rate as of March 31, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. In April 2018, Entergy Arkansas renewed its credit facility through April 2019. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. Entergy Mississippi expects to renew its credit facilities prior to expiration. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $23.8 million Entergy Mississippi $40 million 0.70% $16.6 million Entergy New Orleans $15 million 1.00% $4.8 million Entergy Texas $50 million 0.70% $25.6 million (a) As of March 31, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through October 31, 2019. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2018 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $124 Entergy Louisiana $450 $— Entergy Mississippi $175 $75 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facility Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $145 million that expires in November 2020. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of March 31, 2018 , $118 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the three months ended March 31, 2018 was 3.10% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of March 31, 2018 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 3.74% $43.9 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.82% $52.3 Entergy Louisiana Waterford VIE May 2019 $85 3.35% $62.9 (b) System Energy VIE May 2019 $120 3.46% $43.2 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) The total amount outstanding as of March 31, 2018 is commercial paper, and is classified as a current liability. 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 March 31, 2018 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million System Energy VIE 3.42% Series J due April 2021 $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Louisiana) In March 2018, Entergy Louisiana issued $750 million of 4.00% collateral trust mortgage bonds due March 2033. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and St. Charles Power Station; to repay, at maturity, its $375 million of 6.0% Series first mortgage bonds due May 2018; to repay borrowings from the money pool; to repay borrowings under its $350 million credit facility; and for general corporate purposes. (System Energy) In March 2018 the System Energy nuclear fuel trust variable interest entity issued $100 million of 3.42% Series J notes due April 2021. The System Energy nuclear fuel trust variable interest entity used the proceeds to purchase additional nuclear fuel. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,851,636 $16,771,585 Entergy Arkansas $2,978,569 $2,812,019 Entergy Louisiana $6,938,439 $7,022,323 Entergy Mississippi $1,270,399 $1,252,877 Entergy New Orleans $436,995 $446,981 Entergy Texas $1,562,555 $1,603,892 System Energy $601,582 $576,121 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $184 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Mississippi [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in August 2022. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the three months ended March 31, 2018 was 3.31% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $1,125 $6 $2,369 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At March 31, 2018 , Entergy Corporation had $655 million of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2018 was 1.88% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2018 Letters of Credit Outstanding as of March 31, 2018 Entergy Arkansas April 2018 $20 million (b) 3.14% $— $— Entergy Arkansas August 2022 $150 million (c) 3.12% $50 million $— Entergy Louisiana August 2022 $350 million (c) 2.94% $100 million $9.1 million Entergy Mississippi May 2018 $37.5 million (d) 3.39% $— $— Entergy Mississippi May 2018 $35 million (d) 3.39% $— $— Entergy Mississippi May 2018 $20 million (d) 3.39% $— $— Entergy Mississippi May 2018 $10 million (d) 3.39% $— $— Entergy New Orleans November 2018 $25 million (c) 3.36% $— $0.8 million Entergy Texas August 2022 $150 million (c) 3.39% $— $24.4 million (a) For credit facilities with no borrowings as of March 31, 2018, the interest rate is the estimated interest rate as of March 31, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. In April 2018, Entergy Arkansas renewed its credit facility through April 2019. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. Entergy Mississippi expects to renew its credit facilities prior to expiration. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $23.8 million Entergy Mississippi $40 million 0.70% $16.6 million Entergy New Orleans $15 million 1.00% $4.8 million Entergy Texas $50 million 0.70% $25.6 million (a) As of March 31, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through October 31, 2019. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2018 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $124 Entergy Louisiana $450 $— Entergy Mississippi $175 $75 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facility Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $145 million that expires in November 2020. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of March 31, 2018 , $118 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the three months ended March 31, 2018 was 3.10% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of March 31, 2018 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 3.74% $43.9 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.82% $52.3 Entergy Louisiana Waterford VIE May 2019 $85 3.35% $62.9 (b) System Energy VIE May 2019 $120 3.46% $43.2 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) The total amount outstanding as of March 31, 2018 is commercial paper, and is classified as a current liability. 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 March 31, 2018 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million System Energy VIE 3.42% Series J due April 2021 $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Louisiana) In March 2018, Entergy Louisiana issued $750 million of 4.00% collateral trust mortgage bonds due March 2033. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and St. Charles Power Station; to repay, at maturity, its $375 million of 6.0% Series first mortgage bonds due May 2018; to repay borrowings from the money pool; to repay borrowings under its $350 million credit facility; and for general corporate purposes. (System Energy) In March 2018 the System Energy nuclear fuel trust variable interest entity issued $100 million of 3.42% Series J notes due April 2021. The System Energy nuclear fuel trust variable interest entity used the proceeds to purchase additional nuclear fuel. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,851,636 $16,771,585 Entergy Arkansas $2,978,569 $2,812,019 Entergy Louisiana $6,938,439 $7,022,323 Entergy Mississippi $1,270,399 $1,252,877 Entergy New Orleans $436,995 $446,981 Entergy Texas $1,562,555 $1,603,892 System Energy $601,582 $576,121 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $184 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy New Orleans [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in August 2022. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the three months ended March 31, 2018 was 3.31% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $1,125 $6 $2,369 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At March 31, 2018 , Entergy Corporation had $655 million of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2018 was 1.88% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2018 Letters of Credit Outstanding as of March 31, 2018 Entergy Arkansas April 2018 $20 million (b) 3.14% $— $— Entergy Arkansas August 2022 $150 million (c) 3.12% $50 million $— Entergy Louisiana August 2022 $350 million (c) 2.94% $100 million $9.1 million Entergy Mississippi May 2018 $37.5 million (d) 3.39% $— $— Entergy Mississippi May 2018 $35 million (d) 3.39% $— $— Entergy Mississippi May 2018 $20 million (d) 3.39% $— $— Entergy Mississippi May 2018 $10 million (d) 3.39% $— $— Entergy New Orleans November 2018 $25 million (c) 3.36% $— $0.8 million Entergy Texas August 2022 $150 million (c) 3.39% $— $24.4 million (a) For credit facilities with no borrowings as of March 31, 2018, the interest rate is the estimated interest rate as of March 31, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. In April 2018, Entergy Arkansas renewed its credit facility through April 2019. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. Entergy Mississippi expects to renew its credit facilities prior to expiration. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $23.8 million Entergy Mississippi $40 million 0.70% $16.6 million Entergy New Orleans $15 million 1.00% $4.8 million Entergy Texas $50 million 0.70% $25.6 million (a) As of March 31, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through October 31, 2019. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2018 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $124 Entergy Louisiana $450 $— Entergy Mississippi $175 $75 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facility Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $145 million that expires in November 2020. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of March 31, 2018 , $118 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the three months ended March 31, 2018 was 3.10% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of March 31, 2018 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 3.74% $43.9 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.82% $52.3 Entergy Louisiana Waterford VIE May 2019 $85 3.35% $62.9 (b) System Energy VIE May 2019 $120 3.46% $43.2 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) The total amount outstanding as of March 31, 2018 is commercial paper, and is classified as a current liability. 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 March 31, 2018 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million System Energy VIE 3.42% Series J due April 2021 $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Louisiana) In March 2018, Entergy Louisiana issued $750 million of 4.00% collateral trust mortgage bonds due March 2033. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and St. Charles Power Station; to repay, at maturity, its $375 million of 6.0% Series first mortgage bonds due May 2018; to repay borrowings from the money pool; to repay borrowings under its $350 million credit facility; and for general corporate purposes. (System Energy) In March 2018 the System Energy nuclear fuel trust variable interest entity issued $100 million of 3.42% Series J notes due April 2021. The System Energy nuclear fuel trust variable interest entity used the proceeds to purchase additional nuclear fuel. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,851,636 $16,771,585 Entergy Arkansas $2,978,569 $2,812,019 Entergy Louisiana $6,938,439 $7,022,323 Entergy Mississippi $1,270,399 $1,252,877 Entergy New Orleans $436,995 $446,981 Entergy Texas $1,562,555 $1,603,892 System Energy $601,582 $576,121 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $184 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Texas [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in August 2022. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the three months ended March 31, 2018 was 3.31% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $1,125 $6 $2,369 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At March 31, 2018 , Entergy Corporation had $655 million of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2018 was 1.88% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2018 Letters of Credit Outstanding as of March 31, 2018 Entergy Arkansas April 2018 $20 million (b) 3.14% $— $— Entergy Arkansas August 2022 $150 million (c) 3.12% $50 million $— Entergy Louisiana August 2022 $350 million (c) 2.94% $100 million $9.1 million Entergy Mississippi May 2018 $37.5 million (d) 3.39% $— $— Entergy Mississippi May 2018 $35 million (d) 3.39% $— $— Entergy Mississippi May 2018 $20 million (d) 3.39% $— $— Entergy Mississippi May 2018 $10 million (d) 3.39% $— $— Entergy New Orleans November 2018 $25 million (c) 3.36% $— $0.8 million Entergy Texas August 2022 $150 million (c) 3.39% $— $24.4 million (a) For credit facilities with no borrowings as of March 31, 2018, the interest rate is the estimated interest rate as of March 31, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. In April 2018, Entergy Arkansas renewed its credit facility through April 2019. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. Entergy Mississippi expects to renew its credit facilities prior to expiration. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $23.8 million Entergy Mississippi $40 million 0.70% $16.6 million Entergy New Orleans $15 million 1.00% $4.8 million Entergy Texas $50 million 0.70% $25.6 million (a) As of March 31, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through October 31, 2019. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2018 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $124 Entergy Louisiana $450 $— Entergy Mississippi $175 $75 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facility Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $145 million that expires in November 2020. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of March 31, 2018 , $118 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the three months ended March 31, 2018 was 3.10% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of March 31, 2018 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 3.74% $43.9 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.82% $52.3 Entergy Louisiana Waterford VIE May 2019 $85 3.35% $62.9 (b) System Energy VIE May 2019 $120 3.46% $43.2 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) The total amount outstanding as of March 31, 2018 is commercial paper, and is classified as a current liability. 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 March 31, 2018 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million System Energy VIE 3.42% Series J due April 2021 $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Louisiana) In March 2018, Entergy Louisiana issued $750 million of 4.00% collateral trust mortgage bonds due March 2033. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and St. Charles Power Station; to repay, at maturity, its $375 million of 6.0% Series first mortgage bonds due May 2018; to repay borrowings from the money pool; to repay borrowings under its $350 million credit facility; and for general corporate purposes. (System Energy) In March 2018 the System Energy nuclear fuel trust variable interest entity issued $100 million of 3.42% Series J notes due April 2021. The System Energy nuclear fuel trust variable interest entity used the proceeds to purchase additional nuclear fuel. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,851,636 $16,771,585 Entergy Arkansas $2,978,569 $2,812,019 Entergy Louisiana $6,938,439 $7,022,323 Entergy Mississippi $1,270,399 $1,252,877 Entergy New Orleans $436,995 $446,981 Entergy Texas $1,562,555 $1,603,892 System Energy $601,582 $576,121 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $184 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
System Energy [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in August 2022. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the three months ended March 31, 2018 was 3.31% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $1,125 $6 $2,369 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion . At March 31, 2018 , Entergy Corporation had $655 million of commercial paper outstanding. The weighted-average interest rate for the three months ended March 31, 2018 was 1.88% . Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2018 Letters of Credit Outstanding as of March 31, 2018 Entergy Arkansas April 2018 $20 million (b) 3.14% $— $— Entergy Arkansas August 2022 $150 million (c) 3.12% $50 million $— Entergy Louisiana August 2022 $350 million (c) 2.94% $100 million $9.1 million Entergy Mississippi May 2018 $37.5 million (d) 3.39% $— $— Entergy Mississippi May 2018 $35 million (d) 3.39% $— $— Entergy Mississippi May 2018 $20 million (d) 3.39% $— $— Entergy Mississippi May 2018 $10 million (d) 3.39% $— $— Entergy New Orleans November 2018 $25 million (c) 3.36% $— $0.8 million Entergy Texas August 2022 $150 million (c) 3.39% $— $24.4 million (a) For credit facilities with no borrowings as of March 31, 2018, the interest rate is the estimated interest rate as of March 31, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. In April 2018, Entergy Arkansas renewed its credit facility through April 2019. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. Entergy Mississippi expects to renew its credit facilities prior to expiration. The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $23.8 million Entergy Mississippi $40 million 0.70% $16.6 million Entergy New Orleans $15 million 1.00% $4.8 million Entergy Texas $50 million 0.70% $25.6 million (a) As of March 31, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through October 31, 2019. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2018 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $124 Entergy Louisiana $450 $— Entergy Mississippi $175 $75 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— Entergy Nuclear Vermont Yankee Credit Facility Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $145 million that expires in November 2020. Entergy Nuclear Vermont Yankee does not have the ability to issue letters of credit against the credit facility. This facility provides working capital to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Vermont Yankee. The commitment fee is currently 0.20% of the undrawn commitment amount. As of March 31, 2018 , $118 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the three months ended March 31, 2018 was 3.10% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of March 31, 2018 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 3.74% $43.9 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.82% $52.3 Entergy Louisiana Waterford VIE May 2019 $85 3.35% $62.9 (b) System Energy VIE May 2019 $120 3.46% $43.2 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) The total amount outstanding as of March 31, 2018 is commercial paper, and is classified as a current liability. 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 March 31, 2018 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million System Energy VIE 3.42% Series J due April 2021 $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Louisiana) In March 2018, Entergy Louisiana issued $750 million of 4.00% collateral trust mortgage bonds due March 2033. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and St. Charles Power Station; to repay, at maturity, its $375 million of 6.0% Series first mortgage bonds due May 2018; to repay borrowings from the money pool; to repay borrowings under its $350 million credit facility; and for general corporate purposes. (System Energy) In March 2018 the System Energy nuclear fuel trust variable interest entity issued $100 million of 3.42% Series J notes due April 2021. The System Energy nuclear fuel trust variable interest entity used the proceeds to purchase additional nuclear fuel. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,851,636 $16,771,585 Entergy Arkansas $2,978,569 $2,812,019 Entergy Louisiana $6,938,439 $7,022,323 Entergy Mississippi $1,270,399 $1,252,877 Entergy New Orleans $436,995 $446,981 Entergy Texas $1,562,555 $1,603,892 System Energy $601,582 $576,121 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $184 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Stock-Based Compensation

Stock-Based Compensation	3 Months Ended
	Mar. 31, 2018
Stock-Based Compensation	STOCK-BASED COMPENSATION (Entergy Corporation) Entergy grants stock and stock-based awards, which are described more fully in Note 12 to the financial statements in the Form 10-K. Awards under Entergy’s plans generally vest over three years. Stock Options Entergy granted options on 687,400 shares of its common stock under the 2015 Equity Ownership Plan during the first quarter 2018 with a fair value of $6.99 per option. As of March 31, 2018 , there were options on 4,393,990 shares of common stock outstanding with a weighted-average exercise price of $74.39 . The intrinsic value, which has no effect on net income, of the outstanding stock options is calculated by the positive difference between the weighted average exercise price of the stock options granted and Entergy Corporation’s common stock price as of March 31, 2018 . The aggregate intrinsic value of the stock options outstanding as of March 31, 2018 was $19.3 million . The following table includes financial information for outstanding stock options for the three months ended March 31, 2018 and 2017 : 2018 2017 (In Millions) Compensation expense included in Entergy’s net income $1.1 $1.1 Tax benefit recognized in Entergy’s net income $0.3 $0.4 Compensation cost capitalized as part of fixed assets and inventory $0.2 $0.2 Other Equity Awards In January 2018 the Board approved and Entergy granted 333,850 restricted stock awards and 182,408 long-term incentive awards under the 2015 Equity Ownership Plan. The restricted stock awards were made effective as of January 25, 2018 and were valued at $78.08 per share, which was the closing price of Entergy’s common stock on that date. One-third of the restricted stock awards will vest upon each anniversary of the grant date. In addition, long-term incentive awards were granted in the form of performance units that represent the value of, and are settled with, one share of Entergy Corporation common stock at the end of the three-year performance period, plus dividends accrued during the performance period on the number of performance units earned. Beginning with the 2018-2020 performance period, a cumulative utility earnings metric has been added to the Long-Term Performance Unit Program to supplement the relative total shareholder return measure that historically has been used in this program with each measure equally weighted. The performance units were granted effective as of January 25, 2018 and half were valued at $78.08 per share, the closing price of Entergy’s common stock on that date; and half were valued at $86.75 per share based on various factors, primarily market conditions. See Note 12 to the financial statements in the Form 10-K for a description of the Long-Term Performance Unit Program. Shares of restricted stock have the same dividend and voting rights as other common stock, are considered issued and outstanding shares of Entergy upon vesting, and are expensed ratably over the 3 -year vesting period. Performance units have the same dividend rights as shares of Entergy common stock, are considered issued and outstanding shares of Entergy upon vesting, and are expensed ratably over the 3 -year vesting period. The following table includes financial information for other outstanding equity awards for the three months ended March 31, 2018 and 2017 : 2018 2017 (In Millions) Compensation expense included in Entergy’s net income $8.8 $8.2 Tax benefit recognized in Entergy’s net income $2.2 $3.1 Compensation cost capitalized as part of fixed assets and inventory $2.3 $2.0

Retirement And Other Postretire

Retirement And Other Postretirement Benefits	3 Months Ended
	Mar. 31, 2018
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” effective January 1, 2018. The ASU requires entities to report the service cost component of defined benefit pension cost and postretirement benefit cost (net benefit cost) in the same line item as other compensation costs arising from services rendered during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented in miscellaneous - net in other income. The amendment regarding the presentation of net benefit cost was required to be applied retrospectively for all periods presented. In addition, the ASU allows only the service cost component of net benefit cost to be eligible for capitalization on a prospective basis. In accordance with the regulatory treatment of net benefit cost of the Registrant Subsidiaries, a regulatory asset/liability will be recorded in other regulatory assets/liabilities for the non-service cost components of net benefit cost that would have been capitalized. The retroactive presentation changes resulted in decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income for the three months ended March 31, 2017, with no change in net income, of $21 million for Entergy, $2.8 million for Entergy Arkansas, $6.1 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, ($0.2) million for Entergy Texas, and $0.9 million for System Energy. The retroactive effect of the change for the year ended December 31, 2017 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $108 million for Entergy, $13.7 million for Entergy Arkansas, $27.8 million for Entergy Louisiana, $2.7 million for Entergy Mississippi, $1.3 million for Entergy New Orleans, $0.2 million for Entergy Texas, and $6.2 million for System Energy. The retroactive effect of the change for the year ended December 31, 2016 would be decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income, with no change in net income, of $71 million for Entergy, $13.4 million for Entergy Arkansas, $26.1 million for Entergy Louisiana, $2.4 million for Entergy Mississippi, $1 million for Entergy New Orleans, ($1.1) million for Entergy Texas, and $5.1 million for System Energy. The retroactive effect of the change for the year ended December 31, 2015 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $148 million for Entergy, $30.7 million for Entergy Arkansas, $50.7 million for Entergy Louisiana, $6.3 million for Entergy Mississippi, $4 million for Entergy New Orleans, $4 million for Entergy Texas, and $10.2 million for System Energy. Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projects benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 Non-Qualified Net Pension Cost Entergy recognized $8.9 million and $4.6 million in pension cost for its non-qualified pension plans in the first quarters of 2018 and 2017 , respectively. Reflected in the pension cost for non-qualified pension plans in the first quarter of 2018 is a $4.4 million settlement charge related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $132 $50 $80 $21 $137 2017 $105 $48 $64 $18 $127 Reflected in Entergy Arkansas’s non-qualified pension costs in the first quarter of 2018 is $12 thousand in settlement charges related to the payment of lump sum benefits out of this plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($70 ) $5,426 Amortization of loss (21,957 ) (1,932 ) (1,063 ) (24,952 ) Settlement loss — — (1,616 ) (1,616 ) ($22,056 ) $3,663 ($2,749 ) ($21,142 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,717 ($90 ) $6,562 Amortization of loss (18,450 ) (2,202 ) (919 ) (21,571 ) ($18,515 ) $4,515 ($1,009 ) ($15,009 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Employer Contributions Based on current assumptions, Entergy expects to contribute $352.1 million to its qualified pension plans in 2018. As of March 31, 2018 , Entergy had contributed $91.8 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,917 $14,933 $7,250 $10,883 $13,786 Pension contributions made through March 2018 $17,373 $19,510 $4,194 $2,061 $3,873 $3,715 Remaining estimated pension contributions to be made in 2018 $46,689 $52,407 $10,739 $5,189 $7,010 $10,071
Entergy Arkansas [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” effective January 1, 2018. The ASU requires entities to report the service cost component of defined benefit pension cost and postretirement benefit cost (net benefit cost) in the same line item as other compensation costs arising from services rendered during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented in miscellaneous - net in other income. The amendment regarding the presentation of net benefit cost was required to be applied retrospectively for all periods presented. In addition, the ASU allows only the service cost component of net benefit cost to be eligible for capitalization on a prospective basis. In accordance with the regulatory treatment of net benefit cost of the Registrant Subsidiaries, a regulatory asset/liability will be recorded in other regulatory assets/liabilities for the non-service cost components of net benefit cost that would have been capitalized. The retroactive presentation changes resulted in decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income for the three months ended March 31, 2017, with no change in net income, of $21 million for Entergy, $2.8 million for Entergy Arkansas, $6.1 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, ($0.2) million for Entergy Texas, and $0.9 million for System Energy. The retroactive effect of the change for the year ended December 31, 2017 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $108 million for Entergy, $13.7 million for Entergy Arkansas, $27.8 million for Entergy Louisiana, $2.7 million for Entergy Mississippi, $1.3 million for Entergy New Orleans, $0.2 million for Entergy Texas, and $6.2 million for System Energy. The retroactive effect of the change for the year ended December 31, 2016 would be decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income, with no change in net income, of $71 million for Entergy, $13.4 million for Entergy Arkansas, $26.1 million for Entergy Louisiana, $2.4 million for Entergy Mississippi, $1 million for Entergy New Orleans, ($1.1) million for Entergy Texas, and $5.1 million for System Energy. The retroactive effect of the change for the year ended December 31, 2015 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $148 million for Entergy, $30.7 million for Entergy Arkansas, $50.7 million for Entergy Louisiana, $6.3 million for Entergy Mississippi, $4 million for Entergy New Orleans, $4 million for Entergy Texas, and $10.2 million for System Energy. Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projects benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 Non-Qualified Net Pension Cost Entergy recognized $8.9 million and $4.6 million in pension cost for its non-qualified pension plans in the first quarters of 2018 and 2017 , respectively. Reflected in the pension cost for non-qualified pension plans in the first quarter of 2018 is a $4.4 million settlement charge related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $132 $50 $80 $21 $137 2017 $105 $48 $64 $18 $127 Reflected in Entergy Arkansas’s non-qualified pension costs in the first quarter of 2018 is $12 thousand in settlement charges related to the payment of lump sum benefits out of this plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($70 ) $5,426 Amortization of loss (21,957 ) (1,932 ) (1,063 ) (24,952 ) Settlement loss — — (1,616 ) (1,616 ) ($22,056 ) $3,663 ($2,749 ) ($21,142 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,717 ($90 ) $6,562 Amortization of loss (18,450 ) (2,202 ) (919 ) (21,571 ) ($18,515 ) $4,515 ($1,009 ) ($15,009 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Employer Contributions Based on current assumptions, Entergy expects to contribute $352.1 million to its qualified pension plans in 2018. As of March 31, 2018 , Entergy had contributed $91.8 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,917 $14,933 $7,250 $10,883 $13,786 Pension contributions made through March 2018 $17,373 $19,510 $4,194 $2,061 $3,873 $3,715 Remaining estimated pension contributions to be made in 2018 $46,689 $52,407 $10,739 $5,189 $7,010 $10,071
Entergy Louisiana [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” effective January 1, 2018. The ASU requires entities to report the service cost component of defined benefit pension cost and postretirement benefit cost (net benefit cost) in the same line item as other compensation costs arising from services rendered during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented in miscellaneous - net in other income. The amendment regarding the presentation of net benefit cost was required to be applied retrospectively for all periods presented. In addition, the ASU allows only the service cost component of net benefit cost to be eligible for capitalization on a prospective basis. In accordance with the regulatory treatment of net benefit cost of the Registrant Subsidiaries, a regulatory asset/liability will be recorded in other regulatory assets/liabilities for the non-service cost components of net benefit cost that would have been capitalized. The retroactive presentation changes resulted in decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income for the three months ended March 31, 2017, with no change in net income, of $21 million for Entergy, $2.8 million for Entergy Arkansas, $6.1 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, ($0.2) million for Entergy Texas, and $0.9 million for System Energy. The retroactive effect of the change for the year ended December 31, 2017 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $108 million for Entergy, $13.7 million for Entergy Arkansas, $27.8 million for Entergy Louisiana, $2.7 million for Entergy Mississippi, $1.3 million for Entergy New Orleans, $0.2 million for Entergy Texas, and $6.2 million for System Energy. The retroactive effect of the change for the year ended December 31, 2016 would be decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income, with no change in net income, of $71 million for Entergy, $13.4 million for Entergy Arkansas, $26.1 million for Entergy Louisiana, $2.4 million for Entergy Mississippi, $1 million for Entergy New Orleans, ($1.1) million for Entergy Texas, and $5.1 million for System Energy. The retroactive effect of the change for the year ended December 31, 2015 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $148 million for Entergy, $30.7 million for Entergy Arkansas, $50.7 million for Entergy Louisiana, $6.3 million for Entergy Mississippi, $4 million for Entergy New Orleans, $4 million for Entergy Texas, and $10.2 million for System Energy. Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projects benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 Non-Qualified Net Pension Cost Entergy recognized $8.9 million and $4.6 million in pension cost for its non-qualified pension plans in the first quarters of 2018 and 2017 , respectively. Reflected in the pension cost for non-qualified pension plans in the first quarter of 2018 is a $4.4 million settlement charge related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $132 $50 $80 $21 $137 2017 $105 $48 $64 $18 $127 Reflected in Entergy Arkansas’s non-qualified pension costs in the first quarter of 2018 is $12 thousand in settlement charges related to the payment of lump sum benefits out of this plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($70 ) $5,426 Amortization of loss (21,957 ) (1,932 ) (1,063 ) (24,952 ) Settlement loss — — (1,616 ) (1,616 ) ($22,056 ) $3,663 ($2,749 ) ($21,142 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,717 ($90 ) $6,562 Amortization of loss (18,450 ) (2,202 ) (919 ) (21,571 ) ($18,515 ) $4,515 ($1,009 ) ($15,009 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Employer Contributions Based on current assumptions, Entergy expects to contribute $352.1 million to its qualified pension plans in 2018. As of March 31, 2018 , Entergy had contributed $91.8 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,917 $14,933 $7,250 $10,883 $13,786 Pension contributions made through March 2018 $17,373 $19,510 $4,194 $2,061 $3,873 $3,715 Remaining estimated pension contributions to be made in 2018 $46,689 $52,407 $10,739 $5,189 $7,010 $10,071
Entergy Mississippi [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” effective January 1, 2018. The ASU requires entities to report the service cost component of defined benefit pension cost and postretirement benefit cost (net benefit cost) in the same line item as other compensation costs arising from services rendered during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented in miscellaneous - net in other income. The amendment regarding the presentation of net benefit cost was required to be applied retrospectively for all periods presented. In addition, the ASU allows only the service cost component of net benefit cost to be eligible for capitalization on a prospective basis. In accordance with the regulatory treatment of net benefit cost of the Registrant Subsidiaries, a regulatory asset/liability will be recorded in other regulatory assets/liabilities for the non-service cost components of net benefit cost that would have been capitalized. The retroactive presentation changes resulted in decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income for the three months ended March 31, 2017, with no change in net income, of $21 million for Entergy, $2.8 million for Entergy Arkansas, $6.1 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, ($0.2) million for Entergy Texas, and $0.9 million for System Energy. The retroactive effect of the change for the year ended December 31, 2017 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $108 million for Entergy, $13.7 million for Entergy Arkansas, $27.8 million for Entergy Louisiana, $2.7 million for Entergy Mississippi, $1.3 million for Entergy New Orleans, $0.2 million for Entergy Texas, and $6.2 million for System Energy. The retroactive effect of the change for the year ended December 31, 2016 would be decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income, with no change in net income, of $71 million for Entergy, $13.4 million for Entergy Arkansas, $26.1 million for Entergy Louisiana, $2.4 million for Entergy Mississippi, $1 million for Entergy New Orleans, ($1.1) million for Entergy Texas, and $5.1 million for System Energy. The retroactive effect of the change for the year ended December 31, 2015 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $148 million for Entergy, $30.7 million for Entergy Arkansas, $50.7 million for Entergy Louisiana, $6.3 million for Entergy Mississippi, $4 million for Entergy New Orleans, $4 million for Entergy Texas, and $10.2 million for System Energy. Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projects benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 Non-Qualified Net Pension Cost Entergy recognized $8.9 million and $4.6 million in pension cost for its non-qualified pension plans in the first quarters of 2018 and 2017 , respectively. Reflected in the pension cost for non-qualified pension plans in the first quarter of 2018 is a $4.4 million settlement charge related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $132 $50 $80 $21 $137 2017 $105 $48 $64 $18 $127 Reflected in Entergy Arkansas’s non-qualified pension costs in the first quarter of 2018 is $12 thousand in settlement charges related to the payment of lump sum benefits out of this plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($70 ) $5,426 Amortization of loss (21,957 ) (1,932 ) (1,063 ) (24,952 ) Settlement loss — — (1,616 ) (1,616 ) ($22,056 ) $3,663 ($2,749 ) ($21,142 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,717 ($90 ) $6,562 Amortization of loss (18,450 ) (2,202 ) (919 ) (21,571 ) ($18,515 ) $4,515 ($1,009 ) ($15,009 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Employer Contributions Based on current assumptions, Entergy expects to contribute $352.1 million to its qualified pension plans in 2018. As of March 31, 2018 , Entergy had contributed $91.8 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,917 $14,933 $7,250 $10,883 $13,786 Pension contributions made through March 2018 $17,373 $19,510 $4,194 $2,061 $3,873 $3,715 Remaining estimated pension contributions to be made in 2018 $46,689 $52,407 $10,739 $5,189 $7,010 $10,071
Entergy New Orleans [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” effective January 1, 2018. The ASU requires entities to report the service cost component of defined benefit pension cost and postretirement benefit cost (net benefit cost) in the same line item as other compensation costs arising from services rendered during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented in miscellaneous - net in other income. The amendment regarding the presentation of net benefit cost was required to be applied retrospectively for all periods presented. In addition, the ASU allows only the service cost component of net benefit cost to be eligible for capitalization on a prospective basis. In accordance with the regulatory treatment of net benefit cost of the Registrant Subsidiaries, a regulatory asset/liability will be recorded in other regulatory assets/liabilities for the non-service cost components of net benefit cost that would have been capitalized. The retroactive presentation changes resulted in decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income for the three months ended March 31, 2017, with no change in net income, of $21 million for Entergy, $2.8 million for Entergy Arkansas, $6.1 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, ($0.2) million for Entergy Texas, and $0.9 million for System Energy. The retroactive effect of the change for the year ended December 31, 2017 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $108 million for Entergy, $13.7 million for Entergy Arkansas, $27.8 million for Entergy Louisiana, $2.7 million for Entergy Mississippi, $1.3 million for Entergy New Orleans, $0.2 million for Entergy Texas, and $6.2 million for System Energy. The retroactive effect of the change for the year ended December 31, 2016 would be decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income, with no change in net income, of $71 million for Entergy, $13.4 million for Entergy Arkansas, $26.1 million for Entergy Louisiana, $2.4 million for Entergy Mississippi, $1 million for Entergy New Orleans, ($1.1) million for Entergy Texas, and $5.1 million for System Energy. The retroactive effect of the change for the year ended December 31, 2015 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $148 million for Entergy, $30.7 million for Entergy Arkansas, $50.7 million for Entergy Louisiana, $6.3 million for Entergy Mississippi, $4 million for Entergy New Orleans, $4 million for Entergy Texas, and $10.2 million for System Energy. Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projects benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 Non-Qualified Net Pension Cost Entergy recognized $8.9 million and $4.6 million in pension cost for its non-qualified pension plans in the first quarters of 2018 and 2017 , respectively. Reflected in the pension cost for non-qualified pension plans in the first quarter of 2018 is a $4.4 million settlement charge related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $132 $50 $80 $21 $137 2017 $105 $48 $64 $18 $127 Reflected in Entergy Arkansas’s non-qualified pension costs in the first quarter of 2018 is $12 thousand in settlement charges related to the payment of lump sum benefits out of this plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($70 ) $5,426 Amortization of loss (21,957 ) (1,932 ) (1,063 ) (24,952 ) Settlement loss — — (1,616 ) (1,616 ) ($22,056 ) $3,663 ($2,749 ) ($21,142 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,717 ($90 ) $6,562 Amortization of loss (18,450 ) (2,202 ) (919 ) (21,571 ) ($18,515 ) $4,515 ($1,009 ) ($15,009 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Employer Contributions Based on current assumptions, Entergy expects to contribute $352.1 million to its qualified pension plans in 2018. As of March 31, 2018 , Entergy had contributed $91.8 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,917 $14,933 $7,250 $10,883 $13,786 Pension contributions made through March 2018 $17,373 $19,510 $4,194 $2,061 $3,873 $3,715 Remaining estimated pension contributions to be made in 2018 $46,689 $52,407 $10,739 $5,189 $7,010 $10,071
Entergy Texas [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” effective January 1, 2018. The ASU requires entities to report the service cost component of defined benefit pension cost and postretirement benefit cost (net benefit cost) in the same line item as other compensation costs arising from services rendered during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented in miscellaneous - net in other income. The amendment regarding the presentation of net benefit cost was required to be applied retrospectively for all periods presented. In addition, the ASU allows only the service cost component of net benefit cost to be eligible for capitalization on a prospective basis. In accordance with the regulatory treatment of net benefit cost of the Registrant Subsidiaries, a regulatory asset/liability will be recorded in other regulatory assets/liabilities for the non-service cost components of net benefit cost that would have been capitalized. The retroactive presentation changes resulted in decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income for the three months ended March 31, 2017, with no change in net income, of $21 million for Entergy, $2.8 million for Entergy Arkansas, $6.1 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, ($0.2) million for Entergy Texas, and $0.9 million for System Energy. The retroactive effect of the change for the year ended December 31, 2017 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $108 million for Entergy, $13.7 million for Entergy Arkansas, $27.8 million for Entergy Louisiana, $2.7 million for Entergy Mississippi, $1.3 million for Entergy New Orleans, $0.2 million for Entergy Texas, and $6.2 million for System Energy. The retroactive effect of the change for the year ended December 31, 2016 would be decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income, with no change in net income, of $71 million for Entergy, $13.4 million for Entergy Arkansas, $26.1 million for Entergy Louisiana, $2.4 million for Entergy Mississippi, $1 million for Entergy New Orleans, ($1.1) million for Entergy Texas, and $5.1 million for System Energy. The retroactive effect of the change for the year ended December 31, 2015 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $148 million for Entergy, $30.7 million for Entergy Arkansas, $50.7 million for Entergy Louisiana, $6.3 million for Entergy Mississippi, $4 million for Entergy New Orleans, $4 million for Entergy Texas, and $10.2 million for System Energy. Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projects benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 Non-Qualified Net Pension Cost Entergy recognized $8.9 million and $4.6 million in pension cost for its non-qualified pension plans in the first quarters of 2018 and 2017 , respectively. Reflected in the pension cost for non-qualified pension plans in the first quarter of 2018 is a $4.4 million settlement charge related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $132 $50 $80 $21 $137 2017 $105 $48 $64 $18 $127 Reflected in Entergy Arkansas’s non-qualified pension costs in the first quarter of 2018 is $12 thousand in settlement charges related to the payment of lump sum benefits out of this plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($70 ) $5,426 Amortization of loss (21,957 ) (1,932 ) (1,063 ) (24,952 ) Settlement loss — — (1,616 ) (1,616 ) ($22,056 ) $3,663 ($2,749 ) ($21,142 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,717 ($90 ) $6,562 Amortization of loss (18,450 ) (2,202 ) (919 ) (21,571 ) ($18,515 ) $4,515 ($1,009 ) ($15,009 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Employer Contributions Based on current assumptions, Entergy expects to contribute $352.1 million to its qualified pension plans in 2018. As of March 31, 2018 , Entergy had contributed $91.8 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,917 $14,933 $7,250 $10,883 $13,786 Pension contributions made through March 2018 $17,373 $19,510 $4,194 $2,061 $3,873 $3,715 Remaining estimated pension contributions to be made in 2018 $46,689 $52,407 $10,739 $5,189 $7,010 $10,071
System Energy [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” effective January 1, 2018. The ASU requires entities to report the service cost component of defined benefit pension cost and postretirement benefit cost (net benefit cost) in the same line item as other compensation costs arising from services rendered during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented in miscellaneous - net in other income. The amendment regarding the presentation of net benefit cost was required to be applied retrospectively for all periods presented. In addition, the ASU allows only the service cost component of net benefit cost to be eligible for capitalization on a prospective basis. In accordance with the regulatory treatment of net benefit cost of the Registrant Subsidiaries, a regulatory asset/liability will be recorded in other regulatory assets/liabilities for the non-service cost components of net benefit cost that would have been capitalized. The retroactive presentation changes resulted in decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income for the three months ended March 31, 2017, with no change in net income, of $21 million for Entergy, $2.8 million for Entergy Arkansas, $6.1 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, ($0.2) million for Entergy Texas, and $0.9 million for System Energy. The retroactive effect of the change for the year ended December 31, 2017 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $108 million for Entergy, $13.7 million for Entergy Arkansas, $27.8 million for Entergy Louisiana, $2.7 million for Entergy Mississippi, $1.3 million for Entergy New Orleans, $0.2 million for Entergy Texas, and $6.2 million for System Energy. The retroactive effect of the change for the year ended December 31, 2016 would be decreases (increases) in other operation and maintenance expenses and decreases (increases) in other income, with no change in net income, of $71 million for Entergy, $13.4 million for Entergy Arkansas, $26.1 million for Entergy Louisiana, $2.4 million for Entergy Mississippi, $1 million for Entergy New Orleans, ($1.1) million for Entergy Texas, and $5.1 million for System Energy. The retroactive effect of the change for the year ended December 31, 2015 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of $148 million for Entergy, $30.7 million for Entergy Arkansas, $50.7 million for Entergy Louisiana, $6.3 million for Entergy Mississippi, $4 million for Entergy New Orleans, $4 million for Entergy Texas, and $10.2 million for System Energy. Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projects benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928 Non-Qualified Net Pension Cost Entergy recognized $8.9 million and $4.6 million in pension cost for its non-qualified pension plans in the first quarters of 2018 and 2017 , respectively. Reflected in the pension cost for non-qualified pension plans in the first quarter of 2018 is a $4.4 million settlement charge related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $132 $50 $80 $21 $137 2017 $105 $48 $64 $18 $127 Reflected in Entergy Arkansas’s non-qualified pension costs in the first quarter of 2018 is $12 thousand in settlement charges related to the payment of lump sum benefits out of this plan. Components of Net Other Postretirement Benefit Cost Entergy’s other postretirement benefit cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401 The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174 Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the first quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($70 ) $5,426 Amortization of loss (21,957 ) (1,932 ) (1,063 ) (24,952 ) Settlement loss — — (1,616 ) (1,616 ) ($22,056 ) $3,663 ($2,749 ) ($21,142 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,717 ($90 ) $6,562 Amortization of loss (18,450 ) (2,202 ) (919 ) (21,571 ) ($18,515 ) $4,515 ($1,009 ) ($15,009 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602 Employer Contributions Based on current assumptions, Entergy expects to contribute $352.1 million to its qualified pension plans in 2018. As of March 31, 2018 , Entergy had contributed $91.8 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,917 $14,933 $7,250 $10,883 $13,786 Pension contributions made through March 2018 $17,373 $19,510 $4,194 $2,061 $3,873 $3,715 Remaining estimated pension contributions to be made in 2018 $46,689 $52,407 $10,739 $5,189 $7,010 $10,071

Business Segment Information

Business Segment Information	3 Months Ended
	Mar. 31, 2018
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of March 31, 2018 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the first quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,304,990 $418,924 $— ($33 ) $2,723,881 Income taxes $52,224 ($1,078 ) ($7,483 ) $— $43,663 Consolidated net income (loss) $217,940 ($17,779 ) ($32,063 ) ($31,898 ) $136,200 Total assets as of March 31, 2018 $43,690,561 $5,504,233 $834,463 ($2,747,732 ) $47,281,525 2017 Operating revenues $2,035,112 $553,367 $— ($21 ) $2,588,458 Income taxes $98,492 ($78,337 ) ($12,392 ) $— $7,763 Consolidated net income (loss) $167,623 ($27,197 ) ($22,477 ) ($31,898 ) $86,051 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the first quarter 2018 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 January 1, 2018 $83 $14 $97 Restructuring costs accrued 26 — 26 Balance as of March 31, 2018 $109 $14 $123 Total restructuring charges for the first quarter 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 24 — 24 Balance as of March 31, 2017 $94 $21 $115 In addition, Entergy incurred $73 million in the first quarter 2018 and $212 million in the first quarter 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet of approximately $165 million in 2018, of which $26 million has been incurred as of March 31, 2018, and approximately $205 million from 2019 through mid-2022. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
Entergy Arkansas [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of March 31, 2018 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the first quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,304,990 $418,924 $— ($33 ) $2,723,881 Income taxes $52,224 ($1,078 ) ($7,483 ) $— $43,663 Consolidated net income (loss) $217,940 ($17,779 ) ($32,063 ) ($31,898 ) $136,200 Total assets as of March 31, 2018 $43,690,561 $5,504,233 $834,463 ($2,747,732 ) $47,281,525 2017 Operating revenues $2,035,112 $553,367 $— ($21 ) $2,588,458 Income taxes $98,492 ($78,337 ) ($12,392 ) $— $7,763 Consolidated net income (loss) $167,623 ($27,197 ) ($22,477 ) ($31,898 ) $86,051 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the first quarter 2018 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 January 1, 2018 $83 $14 $97 Restructuring costs accrued 26 — 26 Balance as of March 31, 2018 $109 $14 $123 Total restructuring charges for the first quarter 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 24 — 24 Balance as of March 31, 2017 $94 $21 $115 In addition, Entergy incurred $73 million in the first quarter 2018 and $212 million in the first quarter 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet of approximately $165 million in 2018, of which $26 million has been incurred as of March 31, 2018, and approximately $205 million from 2019 through mid-2022. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
Entergy Louisiana [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of March 31, 2018 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the first quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,304,990 $418,924 $— ($33 ) $2,723,881 Income taxes $52,224 ($1,078 ) ($7,483 ) $— $43,663 Consolidated net income (loss) $217,940 ($17,779 ) ($32,063 ) ($31,898 ) $136,200 Total assets as of March 31, 2018 $43,690,561 $5,504,233 $834,463 ($2,747,732 ) $47,281,525 2017 Operating revenues $2,035,112 $553,367 $— ($21 ) $2,588,458 Income taxes $98,492 ($78,337 ) ($12,392 ) $— $7,763 Consolidated net income (loss) $167,623 ($27,197 ) ($22,477 ) ($31,898 ) $86,051 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the first quarter 2018 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 January 1, 2018 $83 $14 $97 Restructuring costs accrued 26 — 26 Balance as of March 31, 2018 $109 $14 $123 Total restructuring charges for the first quarter 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 24 — 24 Balance as of March 31, 2017 $94 $21 $115 In addition, Entergy incurred $73 million in the first quarter 2018 and $212 million in the first quarter 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet of approximately $165 million in 2018, of which $26 million has been incurred as of March 31, 2018, and approximately $205 million from 2019 through mid-2022. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
Entergy Mississippi [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of March 31, 2018 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the first quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,304,990 $418,924 $— ($33 ) $2,723,881 Income taxes $52,224 ($1,078 ) ($7,483 ) $— $43,663 Consolidated net income (loss) $217,940 ($17,779 ) ($32,063 ) ($31,898 ) $136,200 Total assets as of March 31, 2018 $43,690,561 $5,504,233 $834,463 ($2,747,732 ) $47,281,525 2017 Operating revenues $2,035,112 $553,367 $— ($21 ) $2,588,458 Income taxes $98,492 ($78,337 ) ($12,392 ) $— $7,763 Consolidated net income (loss) $167,623 ($27,197 ) ($22,477 ) ($31,898 ) $86,051 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the first quarter 2018 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 January 1, 2018 $83 $14 $97 Restructuring costs accrued 26 — 26 Balance as of March 31, 2018 $109 $14 $123 Total restructuring charges for the first quarter 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 24 — 24 Balance as of March 31, 2017 $94 $21 $115 In addition, Entergy incurred $73 million in the first quarter 2018 and $212 million in the first quarter 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet of approximately $165 million in 2018, of which $26 million has been incurred as of March 31, 2018, and approximately $205 million from 2019 through mid-2022. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
Entergy New Orleans [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of March 31, 2018 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the first quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,304,990 $418,924 $— ($33 ) $2,723,881 Income taxes $52,224 ($1,078 ) ($7,483 ) $— $43,663 Consolidated net income (loss) $217,940 ($17,779 ) ($32,063 ) ($31,898 ) $136,200 Total assets as of March 31, 2018 $43,690,561 $5,504,233 $834,463 ($2,747,732 ) $47,281,525 2017 Operating revenues $2,035,112 $553,367 $— ($21 ) $2,588,458 Income taxes $98,492 ($78,337 ) ($12,392 ) $— $7,763 Consolidated net income (loss) $167,623 ($27,197 ) ($22,477 ) ($31,898 ) $86,051 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the first quarter 2018 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 January 1, 2018 $83 $14 $97 Restructuring costs accrued 26 — 26 Balance as of March 31, 2018 $109 $14 $123 Total restructuring charges for the first quarter 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 24 — 24 Balance as of March 31, 2017 $94 $21 $115 In addition, Entergy incurred $73 million in the first quarter 2018 and $212 million in the first quarter 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet of approximately $165 million in 2018, of which $26 million has been incurred as of March 31, 2018, and approximately $205 million from 2019 through mid-2022. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
Entergy Texas [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of March 31, 2018 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the first quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,304,990 $418,924 $— ($33 ) $2,723,881 Income taxes $52,224 ($1,078 ) ($7,483 ) $— $43,663 Consolidated net income (loss) $217,940 ($17,779 ) ($32,063 ) ($31,898 ) $136,200 Total assets as of March 31, 2018 $43,690,561 $5,504,233 $834,463 ($2,747,732 ) $47,281,525 2017 Operating revenues $2,035,112 $553,367 $— ($21 ) $2,588,458 Income taxes $98,492 ($78,337 ) ($12,392 ) $— $7,763 Consolidated net income (loss) $167,623 ($27,197 ) ($22,477 ) ($31,898 ) $86,051 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the first quarter 2018 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 January 1, 2018 $83 $14 $97 Restructuring costs accrued 26 — 26 Balance as of March 31, 2018 $109 $14 $123 Total restructuring charges for the first quarter 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 24 — 24 Balance as of March 31, 2017 $94 $21 $115 In addition, Entergy incurred $73 million in the first quarter 2018 and $212 million in the first quarter 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet of approximately $165 million in 2018, of which $26 million has been incurred as of March 31, 2018, and approximately $205 million from 2019 through mid-2022. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
System Energy [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of March 31, 2018 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the first quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,304,990 $418,924 $— ($33 ) $2,723,881 Income taxes $52,224 ($1,078 ) ($7,483 ) $— $43,663 Consolidated net income (loss) $217,940 ($17,779 ) ($32,063 ) ($31,898 ) $136,200 Total assets as of March 31, 2018 $43,690,561 $5,504,233 $834,463 ($2,747,732 ) $47,281,525 2017 Operating revenues $2,035,112 $553,367 $— ($21 ) $2,588,458 Income taxes $98,492 ($78,337 ) ($12,392 ) $— $7,763 Consolidated net income (loss) $167,623 ($27,197 ) ($22,477 ) ($31,898 ) $86,051 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to reduce the size of the merchant fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the first quarter 2018 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 January 1, 2018 $83 $14 $97 Restructuring costs accrued 26 — 26 Balance as of March 31, 2018 $109 $14 $123 Total restructuring charges for the first quarter 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 24 — 24 Balance as of March 31, 2017 $94 $21 $115 In addition, Entergy incurred $73 million in the first quarter 2018 and $212 million in the first quarter 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs are charged to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet of approximately $165 million in 2018, of which $26 million has been incurred as of March 31, 2018, and approximately $205 million from 2019 through mid-2022. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

Risk Management And Fair Values

Risk Management And Fair Values	3 Months Ended
	Mar. 31, 2018
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at March 31, 2018 is approximately 3 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2018 , of which approximately 79% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2018 is 20.7 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of March 31, 2018 , derivative contracts with one counterparty were in a liability position (approximately $0.3 million total). In addition to the corporate guarantee, $0.5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $6 million in cash collateral and $69 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2017 , derivative contracts with eight counterparties were in a liability position (approximately $65 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $4 million in cash collateral and $34 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of short-term natural gas swaps that financially settle against NYMEX futures. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of March 31, 2018 is 63,890,000 MMBtu for Entergy, including 53,730,000 MMBtu for Entergy Louisiana and 10,160,000 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 March 31, 2018 is 18,490 GWh for Entergy, including 4,153 GWh for Entergy Arkansas, 8,162 GWh for Entergy Louisiana, 2,562 GWh for Entergy Mississippi, 943 GWh for Entergy New Orleans, and 2,541 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 March 31, 2018 and December 31, 2017. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Mississippi, and Entergy Texas as of March 31, 2018 and December 31, 2017. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2018 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $63 ($14) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $31 ($5) $26 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $13 ($13) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $9 ($1) $8 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $6 million held as of March 31, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes $69 million in letters of credit held as of March 31, 2018 and $34 million in letters of credit held as of December 31, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options $91 Competitive businesses operating revenues ($30) 2017 Electricity swaps and options $50 Competitive businesses operating revenues $51 (a) Before taxes of ($6) million and $18 million for the three months ended March 31, 2018 and 2017, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended March 31, 2018 and 2017 was $13.3 million and ($1) million , respectively. Based on market prices as of March 31, 2018 , unrealized gains recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $65 million of net unrealized gains. Approximately $41 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues $1 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($7) Financial transmission rights $— Purchased power expense (b) $30 Electricity swaps and options $9 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2018 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $1.9 ($0.1 ) $1.8 Entergy Arkansas Financial transmission rights Prepayments and other $3.8 ($0.4 ) $3.4 Entergy Louisiana Financial transmission rights Prepayments and other $0.9 $— $0.9 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.4 $— $1.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Louisiana Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2 ) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8 ) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2 ) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of March 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.2) (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 $8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($3.5) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($6.1) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $4.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $15.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (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 are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects are calculated for this analysis. This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy and Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Business Unit Risk Control groups report to the Vice President and Treasurer. The Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2018 and December 31, 2017 . The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,148 $— $— $1,148 Decommissioning trust funds (a): Equity securities 577 — — 577 D
Entergy Arkansas [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at March 31, 2018 is approximately 3 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2018 , of which approximately 79% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2018 is 20.7 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of March 31, 2018 , derivative contracts with one counterparty were in a liability position (approximately $0.3 million total). In addition to the corporate guarantee, $0.5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $6 million in cash collateral and $69 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2017 , derivative contracts with eight counterparties were in a liability position (approximately $65 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $4 million in cash collateral and $34 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of short-term natural gas swaps that financially settle against NYMEX futures. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of March 31, 2018 is 63,890,000 MMBtu for Entergy, including 53,730,000 MMBtu for Entergy Louisiana and 10,160,000 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 March 31, 2018 is 18,490 GWh for Entergy, including 4,153 GWh for Entergy Arkansas, 8,162 GWh for Entergy Louisiana, 2,562 GWh for Entergy Mississippi, 943 GWh for Entergy New Orleans, and 2,541 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 March 31, 2018 and December 31, 2017. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Mississippi, and Entergy Texas as of March 31, 2018 and December 31, 2017. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2018 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $63 ($14) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $31 ($5) $26 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $13 ($13) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $9 ($1) $8 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $6 million held as of March 31, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes $69 million in letters of credit held as of March 31, 2018 and $34 million in letters of credit held as of December 31, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options $91 Competitive businesses operating revenues ($30) 2017 Electricity swaps and options $50 Competitive businesses operating revenues $51 (a) Before taxes of ($6) million and $18 million for the three months ended March 31, 2018 and 2017, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended March 31, 2018 and 2017 was $13.3 million and ($1) million , respectively. Based on market prices as of March 31, 2018 , unrealized gains recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $65 million of net unrealized gains. Approximately $41 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues $1 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($7) Financial transmission rights $— Purchased power expense (b) $30 Electricity swaps and options $9 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2018 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $1.9 ($0.1 ) $1.8 Entergy Arkansas Financial transmission rights Prepayments and other $3.8 ($0.4 ) $3.4 Entergy Louisiana Financial transmission rights Prepayments and other $0.9 $— $0.9 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.4 $— $1.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Louisiana Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2 ) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8 ) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2 ) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of March 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.2) (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 $8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($3.5) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($6.1) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $4.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $15.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (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 are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects are calculated for this analysis. This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy and Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Business Unit Risk Control groups report to the Vice President and Treasurer. The Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2018 and December 31, 2017 . The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,148 $— $— $1,148 Decommissioning trust funds (a): Equity securities 577 — — 577 D
Entergy Louisiana [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at March 31, 2018 is approximately 3 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2018 , of which approximately 79% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2018 is 20.7 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of March 31, 2018 , derivative contracts with one counterparty were in a liability position (approximately $0.3 million total). In addition to the corporate guarantee, $0.5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $6 million in cash collateral and $69 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2017 , derivative contracts with eight counterparties were in a liability position (approximately $65 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $4 million in cash collateral and $34 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of short-term natural gas swaps that financially settle against NYMEX futures. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of March 31, 2018 is 63,890,000 MMBtu for Entergy, including 53,730,000 MMBtu for Entergy Louisiana and 10,160,000 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 March 31, 2018 is 18,490 GWh for Entergy, including 4,153 GWh for Entergy Arkansas, 8,162 GWh for Entergy Louisiana, 2,562 GWh for Entergy Mississippi, 943 GWh for Entergy New Orleans, and 2,541 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 March 31, 2018 and December 31, 2017. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Mississippi, and Entergy Texas as of March 31, 2018 and December 31, 2017. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2018 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $63 ($14) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $31 ($5) $26 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $13 ($13) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $9 ($1) $8 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $6 million held as of March 31, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes $69 million in letters of credit held as of March 31, 2018 and $34 million in letters of credit held as of December 31, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options $91 Competitive businesses operating revenues ($30) 2017 Electricity swaps and options $50 Competitive businesses operating revenues $51 (a) Before taxes of ($6) million and $18 million for the three months ended March 31, 2018 and 2017, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended March 31, 2018 and 2017 was $13.3 million and ($1) million , respectively. Based on market prices as of March 31, 2018 , unrealized gains recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $65 million of net unrealized gains. Approximately $41 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues $1 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($7) Financial transmission rights $— Purchased power expense (b) $30 Electricity swaps and options $9 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2018 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $1.9 ($0.1 ) $1.8 Entergy Arkansas Financial transmission rights Prepayments and other $3.8 ($0.4 ) $3.4 Entergy Louisiana Financial transmission rights Prepayments and other $0.9 $— $0.9 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.4 $— $1.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Louisiana Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2 ) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8 ) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2 ) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of March 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.2) (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 $8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($3.5) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($6.1) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $4.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $15.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (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 are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects are calculated for this analysis. This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy and Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Business Unit Risk Control groups report to the Vice President and Treasurer. The Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2018 and December 31, 2017 . The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,148 $— $— $1,148 Decommissioning trust funds (a): Equity securities 577 — — 577 D
Entergy Mississippi [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at March 31, 2018 is approximately 3 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2018 , of which approximately 79% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2018 is 20.7 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of March 31, 2018 , derivative contracts with one counterparty were in a liability position (approximately $0.3 million total). In addition to the corporate guarantee, $0.5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $6 million in cash collateral and $69 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2017 , derivative contracts with eight counterparties were in a liability position (approximately $65 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $4 million in cash collateral and $34 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of short-term natural gas swaps that financially settle against NYMEX futures. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of March 31, 2018 is 63,890,000 MMBtu for Entergy, including 53,730,000 MMBtu for Entergy Louisiana and 10,160,000 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 March 31, 2018 is 18,490 GWh for Entergy, including 4,153 GWh for Entergy Arkansas, 8,162 GWh for Entergy Louisiana, 2,562 GWh for Entergy Mississippi, 943 GWh for Entergy New Orleans, and 2,541 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 March 31, 2018 and December 31, 2017. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Mississippi, and Entergy Texas as of March 31, 2018 and December 31, 2017. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2018 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $63 ($14) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $31 ($5) $26 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $13 ($13) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $9 ($1) $8 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $6 million held as of March 31, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes $69 million in letters of credit held as of March 31, 2018 and $34 million in letters of credit held as of December 31, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options $91 Competitive businesses operating revenues ($30) 2017 Electricity swaps and options $50 Competitive businesses operating revenues $51 (a) Before taxes of ($6) million and $18 million for the three months ended March 31, 2018 and 2017, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended March 31, 2018 and 2017 was $13.3 million and ($1) million , respectively. Based on market prices as of March 31, 2018 , unrealized gains recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $65 million of net unrealized gains. Approximately $41 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues $1 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($7) Financial transmission rights $— Purchased power expense (b) $30 Electricity swaps and options $9 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2018 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $1.9 ($0.1 ) $1.8 Entergy Arkansas Financial transmission rights Prepayments and other $3.8 ($0.4 ) $3.4 Entergy Louisiana Financial transmission rights Prepayments and other $0.9 $— $0.9 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.4 $— $1.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Louisiana Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2 ) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8 ) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2 ) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of March 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.2) (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 $8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($3.5) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($6.1) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $4.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $15.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (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 are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects are calculated for this analysis. This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy and Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Business Unit Risk Control groups report to the Vice President and Treasurer. The Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2018 and December 31, 2017 . The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,148 $— $— $1,148 Decommissioning trust funds (a): Equity securities 577 — — 577 D
Entergy New Orleans [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at March 31, 2018 is approximately 3 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2018 , of which approximately 79% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2018 is 20.7 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of March 31, 2018 , derivative contracts with one counterparty were in a liability position (approximately $0.3 million total). In addition to the corporate guarantee, $0.5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $6 million in cash collateral and $69 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2017 , derivative contracts with eight counterparties were in a liability position (approximately $65 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $4 million in cash collateral and $34 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of short-term natural gas swaps that financially settle against NYMEX futures. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of March 31, 2018 is 63,890,000 MMBtu for Entergy, including 53,730,000 MMBtu for Entergy Louisiana and 10,160,000 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 March 31, 2018 is 18,490 GWh for Entergy, including 4,153 GWh for Entergy Arkansas, 8,162 GWh for Entergy Louisiana, 2,562 GWh for Entergy Mississippi, 943 GWh for Entergy New Orleans, and 2,541 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 March 31, 2018 and December 31, 2017. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Mississippi, and Entergy Texas as of March 31, 2018 and December 31, 2017. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2018 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $63 ($14) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $31 ($5) $26 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $13 ($13) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $9 ($1) $8 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $6 million held as of March 31, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes $69 million in letters of credit held as of March 31, 2018 and $34 million in letters of credit held as of December 31, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options $91 Competitive businesses operating revenues ($30) 2017 Electricity swaps and options $50 Competitive businesses operating revenues $51 (a) Before taxes of ($6) million and $18 million for the three months ended March 31, 2018 and 2017, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended March 31, 2018 and 2017 was $13.3 million and ($1) million , respectively. Based on market prices as of March 31, 2018 , unrealized gains recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $65 million of net unrealized gains. Approximately $41 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues $1 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($7) Financial transmission rights $— Purchased power expense (b) $30 Electricity swaps and options $9 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2018 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $1.9 ($0.1 ) $1.8 Entergy Arkansas Financial transmission rights Prepayments and other $3.8 ($0.4 ) $3.4 Entergy Louisiana Financial transmission rights Prepayments and other $0.9 $— $0.9 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.4 $— $1.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Louisiana Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2 ) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8 ) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2 ) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of March 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.2) (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 $8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($3.5) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($6.1) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $4.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $15.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (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 are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects are calculated for this analysis. This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy and Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Business Unit Risk Control groups report to the Vice President and Treasurer. The Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2018 and December 31, 2017 . The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,148 $— $— $1,148 Decommissioning trust funds (a): Equity securities 577 — — 577 D
Entergy Texas [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at March 31, 2018 is approximately 3 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2018 , of which approximately 79% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2018 is 20.7 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of March 31, 2018 , derivative contracts with one counterparty were in a liability position (approximately $0.3 million total). In addition to the corporate guarantee, $0.5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $6 million in cash collateral and $69 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2017 , derivative contracts with eight counterparties were in a liability position (approximately $65 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $4 million in cash collateral and $34 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of short-term natural gas swaps that financially settle against NYMEX futures. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of March 31, 2018 is 63,890,000 MMBtu for Entergy, including 53,730,000 MMBtu for Entergy Louisiana and 10,160,000 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 March 31, 2018 is 18,490 GWh for Entergy, including 4,153 GWh for Entergy Arkansas, 8,162 GWh for Entergy Louisiana, 2,562 GWh for Entergy Mississippi, 943 GWh for Entergy New Orleans, and 2,541 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 March 31, 2018 and December 31, 2017. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Mississippi, and Entergy Texas as of March 31, 2018 and December 31, 2017. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2018 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $63 ($14) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $31 ($5) $26 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $13 ($13) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $9 ($1) $8 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $6 million held as of March 31, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes $69 million in letters of credit held as of March 31, 2018 and $34 million in letters of credit held as of December 31, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options $91 Competitive businesses operating revenues ($30) 2017 Electricity swaps and options $50 Competitive businesses operating revenues $51 (a) Before taxes of ($6) million and $18 million for the three months ended March 31, 2018 and 2017, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended March 31, 2018 and 2017 was $13.3 million and ($1) million , respectively. Based on market prices as of March 31, 2018 , unrealized gains recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $65 million of net unrealized gains. Approximately $41 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues $1 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($7) Financial transmission rights $— Purchased power expense (b) $30 Electricity swaps and options $9 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2018 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $1.9 ($0.1 ) $1.8 Entergy Arkansas Financial transmission rights Prepayments and other $3.8 ($0.4 ) $3.4 Entergy Louisiana Financial transmission rights Prepayments and other $0.9 $— $0.9 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.4 $— $1.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Louisiana Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2 ) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8 ) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2 ) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of March 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.2) (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 $8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($3.5) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($6.1) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $4.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $15.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (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 are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects are calculated for this analysis. This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy and Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Business Unit Risk Control groups report to the Vice President and Treasurer. The Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2018 and December 31, 2017 . The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,148 $— $— $1,148 Decommissioning trust funds (a): Equity securities 577 — — 577 D
System Energy [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at March 31, 2018 is approximately 3 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2018 , of which approximately 79% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2018 is 20.7 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guaranty, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. As of March 31, 2018 , derivative contracts with one counterparty were in a liability position (approximately $0.3 million total). In addition to the corporate guarantee, $0.5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $6 million in cash collateral and $69 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2017 , derivative contracts with eight counterparties were in a liability position (approximately $65 million total). In addition to the corporate guarantee, $1 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $4 million in cash collateral and $34 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of short-term natural gas swaps that financially settle against NYMEX futures. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy Louisiana and Entergy New Orleans. The total volume of natural gas swaps outstanding as of March 31, 2018 is 63,890,000 MMBtu for Entergy, including 53,730,000 MMBtu for Entergy Louisiana and 10,160,000 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 March 31, 2018 is 18,490 GWh for Entergy, including 4,153 GWh for Entergy Arkansas, 8,162 GWh for Entergy Louisiana, 2,562 GWh for Entergy Mississippi, 943 GWh for Entergy New Orleans, and 2,541 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 March 31, 2018 and December 31, 2017. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Mississippi, and Entergy Texas as of March 31, 2018 and December 31, 2017. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2018 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $63 ($14) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $31 ($5) $26 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $13 ($13) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $9 ($1) $8 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $6 million held as of March 31, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes $69 million in letters of credit held as of March 31, 2018 and $34 million in letters of credit held as of December 31, 2017. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options $91 Competitive businesses operating revenues ($30) 2017 Electricity swaps and options $50 Competitive businesses operating revenues $51 (a) Before taxes of ($6) million and $18 million for the three months ended March 31, 2018 and 2017, respectively At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended March 31, 2018 and 2017 was $13.3 million and ($1) million , respectively. Based on market prices as of March 31, 2018 , unrealized gains recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $65 million of net unrealized gains. Approximately $41 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues $1 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($7) Financial transmission rights $— Purchased power expense (b) $30 Electricity swaps and options $9 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2018 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $1.9 ($0.1 ) $1.8 Entergy Arkansas Financial transmission rights Prepayments and other $3.8 ($0.4 ) $3.4 Entergy Louisiana Financial transmission rights Prepayments and other $0.9 $— $0.9 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.4 $— $1.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Louisiana Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2 ) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8 ) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2 ) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of March 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.2) (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 $8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($3.5) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($6.1) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $4.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $15.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (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 are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects are calculated for this analysis. This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Business Unit Risk Control group. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy and Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Business Unit Risk Control groups report to the Vice President and Treasurer. The Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2018 and December 31, 2017 . The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,148 $— $— $1,148 Decommissioning trust funds (a): Equity securities 577 — — 577 D

Decommissioning Trust Funds

Decommissioning Trust Funds	3 Months Ended
	Mar. 31, 2018
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) Entergy holds equity securities and available-for-sale debt securities 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. Entergy implemented ASU No. 2016-01 “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” effective January 1, 2018. The ASU requires investments in equity securities, excluding those accounted for under the equity method or resulting in consolidation of the investee, to be measured at fair value with changes recognized in net income. Entergy implemented this ASU using a modified retrospective method, and Entergy recorded an adjustment increasing retained earnings and reducing accumulated other comprehensive loss by $633 million as of January 1, 2018 for the cumulative effect of the unrealized gains and losses on investments in equity securities held by the decommissioning trust funds that do not meet the criteria for regulatory accounting treatment. Going forward, unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds will be recorded in earnings as they occur rather than in other comprehensive income. In accordance with the regulatory treatment of the decommissioning trust funds of the Registrant Subsidiaries, an offsetting amount of unrealized gains/(losses) will continue to be recorded in other regulatory liabilities/assets. Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the excess trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for Pilgrim, Indian Point 1, Indian Point 2, Indian Point 3, Vermont Yankee, and Palisades do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/losses recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($64) million . The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 2,619 23 48 2017 Equity Securities $4,662 $2,131 $1 Debt Securities 2,550 44 16 Total $7,212 $2,175 $17 The unrealized gains/(losses) above are reported before deferred taxes of $472 million as of December 31, 2017 for equity securities, and ($2) million as of March 31, 2018 and $7 million as of December 31, 2017 for debt securities. The amortized cost of debt securities was $2,643 million as of March 31, 2018 and $2,539 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 3.26% , an average duration of approximately 6.18 years, and an average maturity of approximately 10.09 years. The fair value and gross unrealized losses of the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1,667 $35 More than 12 months 241 13 Total $1,908 $48 The fair value and gross unrealized losses of available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8 $1 $1,099 $7 More than 12 months — — 265 9 Total $8 $1 $1,364 $16 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $89 $74 1 year - 5 years 928 902 5 years - 10 years 784 812 10 years - 15 years 152 147 15 years - 20 years 101 100 20 years+ 565 515 Total $2,619 $2,550 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $1,091 million and $514 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $1 million and $9 million , respectively, and gross losses of $7 million and $5 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of March 31, 2018 are $485 million for Indian Point 1, $614 million for Indian Point 2, $789 million for Indian Point 3, $453 million for Palisades, $1,048 million for Pilgrim, and $591 million for Vermont Yankee. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2017 are $491 million for Indian Point 1, $621 million for Indian Point 2, $798 million for Indian Point 3, $458 million for Palisades, $1,068 million for Pilgrim, and $613 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 350.8 0.5 9.7 2017 Equity Securities $596.7 $354.9 $— Debt Securities 348.2 2.1 3.0 Total $944.9 $357.0 $3.0 The amortized cost of debt securities was $360 million as of March 31, 2018 and $349.1 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 2.67% , an average duration of approximately 5.48 years, and an average maturity of approximately 6.90 years. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($8) million . 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 the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $277.8 $7.2 More than 12 months 42.5 2.5 Total $320.3 $9.7 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $168.0 $1.2 More than 12 months — — 41.4 1.8 Total $— $— $209.4 $3.0 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $14.1 $13.0 1 year - 5 years 130.6 123.4 5 years - 10 years 177.9 180.6 10 years - 15 years 3.4 4.8 15 years - 20 years 7.0 3.4 20 years+ 17.8 23.0 Total $350.8 $348.2 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $34.9 million and $36 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $0.1 million and $0.5 million , respectively, and gross losses of $0.1 million and $0.1 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 516.3 5.7 8.4 2017 Equity Securities $818.3 $461.2 $— Debt Securities 493.8 10.9 3.6 Total $1,312.1 $472.1 $3.6 The amortized cost of debt securities was $519 million as of March 31, 2018 and $490 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 3.83% , an average duration of approximately 6.05 years, and an average maturity of approximately 11.85 years. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($10.8) million . 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 the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $254.9 $4.6 More than 12 months 78.8 3.8 Total $333.7 $8.4 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $135.3 $1.1 More than 12 months — — 84.4 2.5 Total $— $— $219.7 $3.6 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $28.1 $23.2 1 year - 5 years 136.7 122.8 5 years - 10 years 108.4 109.3 10 years - 15 years 52.9 52.7 15 years - 20 years 44.7 50.7 20 years+ 145.5 135.1 Total $516.3 $493.8 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $125.5 million and $40.6 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $0.5 million and $0.03 million , respectively, and gross losses of $0.8 million and $0.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 325.6 1.4 5.8 2017 Equity Securities $575.2 $308.6 $— Debt Securities 330.5 4.2 1.2 Total $905.7 $312.8 $1.2 The amortized cost of debt securities was $330 million as of March 31, 2018 and $327.5 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 2.72% , an average duration of approximately 6.38 years, and an average maturity of approximately 9.39 years. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($7.8) million . 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 the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $240.7 $5.5 More than 12 months 10.2 0.3 Total $250.9 $5.8 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $196.9 $1.0 More than 12 months — — 10.4 0.2 Total $— $— $207.3 $1.2 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $5.5 $4.1 1 year - 5 years 164.5 173.0 5 years - 10 years 78.4 78.5 10 years - 15 years 3.8 1.0 15 years - 20 years 10.7 6.9 20 years+ 62.7 67.0 Total $325.6 $330.5 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $54.2 million and $75.8 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $0.1 million and $0.1 million , respectively, and gross losses of $0.6 million and $0.7 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates the available-for-sale debt securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred. The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three months ended March 31, 2018 and 2017. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.
Entergy Arkansas [Member]
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) Entergy holds equity securities and available-for-sale debt securities 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. Entergy implemented ASU No. 2016-01 “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” effective January 1, 2018. The ASU requires investments in equity securities, excluding those accounted for under the equity method or resulting in consolidation of the investee, to be measured at fair value with changes recognized in net income. Entergy implemented this ASU using a modified retrospective method, and Entergy recorded an adjustment increasing retained earnings and reducing accumulated other comprehensive loss by $633 million as of January 1, 2018 for the cumulative effect of the unrealized gains and losses on investments in equity securities held by the decommissioning trust funds that do not meet the criteria for regulatory accounting treatment. Going forward, unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds will be recorded in earnings as they occur rather than in other comprehensive income. In accordance with the regulatory treatment of the decommissioning trust funds of the Registrant Subsidiaries, an offsetting amount of unrealized gains/(losses) will continue to be recorded in other regulatory liabilities/assets. Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the excess trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for Pilgrim, Indian Point 1, Indian Point 2, Indian Point 3, Vermont Yankee, and Palisades do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/losses recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($64) million . The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 2,619 23 48 2017 Equity Securities $4,662 $2,131 $1 Debt Securities 2,550 44 16 Total $7,212 $2,175 $17 The unrealized gains/(losses) above are reported before deferred taxes of $472 million as of December 31, 2017 for equity securities, and ($2) million as of March 31, 2018 and $7 million as of December 31, 2017 for debt securities. The amortized cost of debt securities was $2,643 million as of March 31, 2018 and $2,539 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 3.26% , an average duration of approximately 6.18 years, and an average maturity of approximately 10.09 years. The fair value and gross unrealized losses of the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1,667 $35 More than 12 months 241 13 Total $1,908 $48 The fair value and gross unrealized losses of available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8 $1 $1,099 $7 More than 12 months — — 265 9 Total $8 $1 $1,364 $16 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $89 $74 1 year - 5 years 928 902 5 years - 10 years 784 812 10 years - 15 years 152 147 15 years - 20 years 101 100 20 years+ 565 515 Total $2,619 $2,550 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $1,091 million and $514 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $1 million and $9 million , respectively, and gross losses of $7 million and $5 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of March 31, 2018 are $485 million for Indian Point 1, $614 million for Indian Point 2, $789 million for Indian Point 3, $453 million for Palisades, $1,048 million for Pilgrim, and $591 million for Vermont Yankee. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2017 are $491 million for Indian Point 1, $621 million for Indian Point 2, $798 million for Indian Point 3, $458 million for Palisades, $1,068 million for Pilgrim, and $613 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 350.8 0.5 9.7 2017 Equity Securities $596.7 $354.9 $— Debt Securities 348.2 2.1 3.0 Total $944.9 $357.0 $3.0 The amortized cost of debt securities was $360 million as of March 31, 2018 and $349.1 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 2.67% , an average duration of approximately 5.48 years, and an average maturity of approximately 6.90 years. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($8) million . 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 the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $277.8 $7.2 More than 12 months 42.5 2.5 Total $320.3 $9.7 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $168.0 $1.2 More than 12 months — — 41.4 1.8 Total $— $— $209.4 $3.0 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $14.1 $13.0 1 year - 5 years 130.6 123.4 5 years - 10 years 177.9 180.6 10 years - 15 years 3.4 4.8 15 years - 20 years 7.0 3.4 20 years+ 17.8 23.0 Total $350.8 $348.2 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $34.9 million and $36 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $0.1 million and $0.5 million , respectively, and gross losses of $0.1 million and $0.1 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 516.3 5.7 8.4 2017 Equity Securities $818.3 $461.2 $— Debt Securities 493.8 10.9 3.6 Total $1,312.1 $472.1 $3.6 The amortized cost of debt securities was $519 million as of March 31, 2018 and $490 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 3.83% , an average duration of approximately 6.05 years, and an average maturity of approximately 11.85 years. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($10.8) million . 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 the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $254.9 $4.6 More than 12 months 78.8 3.8 Total $333.7 $8.4 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $135.3 $1.1 More than 12 months — — 84.4 2.5 Total $— $— $219.7 $3.6 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $28.1 $23.2 1 year - 5 years 136.7 122.8 5 years - 10 years 108.4 109.3 10 years - 15 years 52.9 52.7 15 years - 20 years 44.7 50.7 20 years+ 145.5 135.1 Total $516.3 $493.8 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $125.5 million and $40.6 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $0.5 million and $0.03 million , respectively, and gross losses of $0.8 million and $0.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 325.6 1.4 5.8 2017 Equity Securities $575.2 $308.6 $— Debt Securities 330.5 4.2 1.2 Total $905.7 $312.8 $1.2 The amortized cost of debt securities was $330 million as of March 31, 2018 and $327.5 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 2.72% , an average duration of approximately 6.38 years, and an average maturity of approximately 9.39 years. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($7.8) million . 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 the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $240.7 $5.5 More than 12 months 10.2 0.3 Total $250.9 $5.8 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $196.9 $1.0 More than 12 months — — 10.4 0.2 Total $— $— $207.3 $1.2 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $5.5 $4.1 1 year - 5 years 164.5 173.0 5 years - 10 years 78.4 78.5 10 years - 15 years 3.8 1.0 15 years - 20 years 10.7 6.9 20 years+ 62.7 67.0 Total $325.6 $330.5 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $54.2 million and $75.8 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $0.1 million and $0.1 million , respectively, and gross losses of $0.6 million and $0.7 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates the available-for-sale debt securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred. The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three months ended March 31, 2018 and 2017. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.
Entergy Louisiana [Member]
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) Entergy holds equity securities and available-for-sale debt securities 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. Entergy implemented ASU No. 2016-01 “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” effective January 1, 2018. The ASU requires investments in equity securities, excluding those accounted for under the equity method or resulting in consolidation of the investee, to be measured at fair value with changes recognized in net income. Entergy implemented this ASU using a modified retrospective method, and Entergy recorded an adjustment increasing retained earnings and reducing accumulated other comprehensive loss by $633 million as of January 1, 2018 for the cumulative effect of the unrealized gains and losses on investments in equity securities held by the decommissioning trust funds that do not meet the criteria for regulatory accounting treatment. Going forward, unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds will be recorded in earnings as they occur rather than in other comprehensive income. In accordance with the regulatory treatment of the decommissioning trust funds of the Registrant Subsidiaries, an offsetting amount of unrealized gains/(losses) will continue to be recorded in other regulatory liabilities/assets. Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the excess trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for Pilgrim, Indian Point 1, Indian Point 2, Indian Point 3, Vermont Yankee, and Palisades do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/losses recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($64) million . The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 2,619 23 48 2017 Equity Securities $4,662 $2,131 $1 Debt Securities 2,550 44 16 Total $7,212 $2,175 $17 The unrealized gains/(losses) above are reported before deferred taxes of $472 million as of December 31, 2017 for equity securities, and ($2) million as of March 31, 2018 and $7 million as of December 31, 2017 for debt securities. The amortized cost of debt securities was $2,643 million as of March 31, 2018 and $2,539 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 3.26% , an average duration of approximately 6.18 years, and an average maturity of approximately 10.09 years. The fair value and gross unrealized losses of the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1,667 $35 More than 12 months 241 13 Total $1,908 $48 The fair value and gross unrealized losses of available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8 $1 $1,099 $7 More than 12 months — — 265 9 Total $8 $1 $1,364 $16 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $89 $74 1 year - 5 years 928 902 5 years - 10 years 784 812 10 years - 15 years 152 147 15 years - 20 years 101 100 20 years+ 565 515 Total $2,619 $2,550 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $1,091 million and $514 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $1 million and $9 million , respectively, and gross losses of $7 million and $5 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of March 31, 2018 are $485 million for Indian Point 1, $614 million for Indian Point 2, $789 million for Indian Point 3, $453 million for Palisades, $1,048 million for Pilgrim, and $591 million for Vermont Yankee. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2017 are $491 million for Indian Point 1, $621 million for Indian Point 2, $798 million for Indian Point 3, $458 million for Palisades, $1,068 million for Pilgrim, and $613 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 350.8 0.5 9.7 2017 Equity Securities $596.7 $354.9 $— Debt Securities 348.2 2.1 3.0 Total $944.9 $357.0 $3.0 The amortized cost of debt securities was $360 million as of March 31, 2018 and $349.1 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 2.67% , an average duration of approximately 5.48 years, and an average maturity of approximately 6.90 years. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($8) million . 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 the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $277.8 $7.2 More than 12 months 42.5 2.5 Total $320.3 $9.7 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $168.0 $1.2 More than 12 months — — 41.4 1.8 Total $— $— $209.4 $3.0 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $14.1 $13.0 1 year - 5 years 130.6 123.4 5 years - 10 years 177.9 180.6 10 years - 15 years 3.4 4.8 15 years - 20 years 7.0 3.4 20 years+ 17.8 23.0 Total $350.8 $348.2 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $34.9 million and $36 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $0.1 million and $0.5 million , respectively, and gross losses of $0.1 million and $0.1 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 516.3 5.7 8.4 2017 Equity Securities $818.3 $461.2 $— Debt Securities 493.8 10.9 3.6 Total $1,312.1 $472.1 $3.6 The amortized cost of debt securities was $519 million as of March 31, 2018 and $490 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 3.83% , an average duration of approximately 6.05 years, and an average maturity of approximately 11.85 years. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($10.8) million . 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 the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $254.9 $4.6 More than 12 months 78.8 3.8 Total $333.7 $8.4 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $135.3 $1.1 More than 12 months — — 84.4 2.5 Total $— $— $219.7 $3.6 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $28.1 $23.2 1 year - 5 years 136.7 122.8 5 years - 10 years 108.4 109.3 10 years - 15 years 52.9 52.7 15 years - 20 years 44.7 50.7 20 years+ 145.5 135.1 Total $516.3 $493.8 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $125.5 million and $40.6 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $0.5 million and $0.03 million , respectively, and gross losses of $0.8 million and $0.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 325.6 1.4 5.8 2017 Equity Securities $575.2 $308.6 $— Debt Securities 330.5 4.2 1.2 Total $905.7 $312.8 $1.2 The amortized cost of debt securities was $330 million as of March 31, 2018 and $327.5 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 2.72% , an average duration of approximately 6.38 years, and an average maturity of approximately 9.39 years. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($7.8) million . 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 the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $240.7 $5.5 More than 12 months 10.2 0.3 Total $250.9 $5.8 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $196.9 $1.0 More than 12 months — — 10.4 0.2 Total $— $— $207.3 $1.2 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $5.5 $4.1 1 year - 5 years 164.5 173.0 5 years - 10 years 78.4 78.5 10 years - 15 years 3.8 1.0 15 years - 20 years 10.7 6.9 20 years+ 62.7 67.0 Total $325.6 $330.5 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $54.2 million and $75.8 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $0.1 million and $0.1 million , respectively, and gross losses of $0.6 million and $0.7 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates the available-for-sale debt securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred. The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three months ended March 31, 2018 and 2017. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.
System Energy [Member]
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) Entergy holds equity securities and available-for-sale debt securities 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. Entergy implemented ASU No. 2016-01 “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities” effective January 1, 2018. The ASU requires investments in equity securities, excluding those accounted for under the equity method or resulting in consolidation of the investee, to be measured at fair value with changes recognized in net income. Entergy implemented this ASU using a modified retrospective method, and Entergy recorded an adjustment increasing retained earnings and reducing accumulated other comprehensive loss by $633 million as of January 1, 2018 for the cumulative effect of the unrealized gains and losses on investments in equity securities held by the decommissioning trust funds that do not meet the criteria for regulatory accounting treatment. Going forward, unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds will be recorded in earnings as they occur rather than in other comprehensive income. In accordance with the regulatory treatment of the decommissioning trust funds of the Registrant Subsidiaries, an offsetting amount of unrealized gains/(losses) will continue to be recorded in other regulatory liabilities/assets. Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the excess trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for Pilgrim, Indian Point 1, Indian Point 2, Indian Point 3, Vermont Yankee, and Palisades do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/losses recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($64) million . The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 2,619 23 48 2017 Equity Securities $4,662 $2,131 $1 Debt Securities 2,550 44 16 Total $7,212 $2,175 $17 The unrealized gains/(losses) above are reported before deferred taxes of $472 million as of December 31, 2017 for equity securities, and ($2) million as of March 31, 2018 and $7 million as of December 31, 2017 for debt securities. The amortized cost of debt securities was $2,643 million as of March 31, 2018 and $2,539 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 3.26% , an average duration of approximately 6.18 years, and an average maturity of approximately 10.09 years. The fair value and gross unrealized losses of the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1,667 $35 More than 12 months 241 13 Total $1,908 $48 The fair value and gross unrealized losses of available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8 $1 $1,099 $7 More than 12 months — — 265 9 Total $8 $1 $1,364 $16 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $89 $74 1 year - 5 years 928 902 5 years - 10 years 784 812 10 years - 15 years 152 147 15 years - 20 years 101 100 20 years+ 565 515 Total $2,619 $2,550 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $1,091 million and $514 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $1 million and $9 million , respectively, and gross losses of $7 million and $5 million , respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of March 31, 2018 are $485 million for Indian Point 1, $614 million for Indian Point 2, $789 million for Indian Point 3, $453 million for Palisades, $1,048 million for Pilgrim, and $591 million for Vermont Yankee. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2017 are $491 million for Indian Point 1, $621 million for Indian Point 2, $798 million for Indian Point 3, $458 million for Palisades, $1,068 million for Pilgrim, and $613 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 350.8 0.5 9.7 2017 Equity Securities $596.7 $354.9 $— Debt Securities 348.2 2.1 3.0 Total $944.9 $357.0 $3.0 The amortized cost of debt securities was $360 million as of March 31, 2018 and $349.1 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 2.67% , an average duration of approximately 5.48 years, and an average maturity of approximately 6.90 years. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($8) million . 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 the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $277.8 $7.2 More than 12 months 42.5 2.5 Total $320.3 $9.7 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $168.0 $1.2 More than 12 months — — 41.4 1.8 Total $— $— $209.4 $3.0 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $14.1 $13.0 1 year - 5 years 130.6 123.4 5 years - 10 years 177.9 180.6 10 years - 15 years 3.4 4.8 15 years - 20 years 7.0 3.4 20 years+ 17.8 23.0 Total $350.8 $348.2 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $34.9 million and $36 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $0.1 million and $0.5 million , respectively, and gross losses of $0.1 million and $0.1 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 516.3 5.7 8.4 2017 Equity Securities $818.3 $461.2 $— Debt Securities 493.8 10.9 3.6 Total $1,312.1 $472.1 $3.6 The amortized cost of debt securities was $519 million as of March 31, 2018 and $490 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 3.83% , an average duration of approximately 6.05 years, and an average maturity of approximately 11.85 years. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($10.8) million . 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 the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $254.9 $4.6 More than 12 months 78.8 3.8 Total $333.7 $8.4 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $135.3 $1.1 More than 12 months — — 84.4 2.5 Total $— $— $219.7 $3.6 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $28.1 $23.2 1 year - 5 years 136.7 122.8 5 years - 10 years 108.4 109.3 10 years - 15 years 52.9 52.7 15 years - 20 years 44.7 50.7 20 years+ 145.5 135.1 Total $516.3 $493.8 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $125.5 million and $40.6 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $0.5 million and $0.03 million , respectively, and gross losses of $0.8 million and $0.2 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 325.6 1.4 5.8 2017 Equity Securities $575.2 $308.6 $— Debt Securities 330.5 4.2 1.2 Total $905.7 $312.8 $1.2 The amortized cost of debt securities was $330 million as of March 31, 2018 and $327.5 million as of December 31, 2017 . As of March 31, 2018 , the debt securities have an average coupon rate of approximately 2.72% , an average duration of approximately 6.38 years, and an average maturity of approximately 9.39 years. The unrealized gains/(losses) recognized during the three months ended March 31, 2018 on equity securities still held as of March 31, 2018 were ($7.8) million . 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 the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $240.7 $5.5 More than 12 months 10.2 0.3 Total $250.9 $5.8 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $196.9 $1.0 More than 12 months — — 10.4 0.2 Total $— $— $207.3 $1.2 The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $5.5 $4.1 1 year - 5 years 164.5 173.0 5 years - 10 years 78.4 78.5 10 years - 15 years 3.8 1.0 15 years - 20 years 10.7 6.9 20 years+ 62.7 67.0 Total $325.6 $330.5 During the three months ended March 31, 2018 and 2017 , proceeds from the dispositions of securities amounted to $54.2 million and $75.8 million , respectively. During the three months ended March 31, 2018 and 2017 , gross gains of $0.1 million and $0.1 million , respectively, and gross losses of $0.6 million and $0.7 million , respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates the available-for-sale debt securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred. The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three months ended March 31, 2018 and 2017. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2018
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. As discussed in the Form 10-K, the Tax Cuts and Jobs Act limits the deduction for net business interest expense in certain circumstances. The limitation does not apply to interest expense allocable to the Utility. In Notice 2018-28 released on April 2, 2018, the IRS announced that it intends to issue proposed regulations that will provide guidance to assist taxpayers in complying with the new interest provisions under the Tax Cuts and Jobs Act. The notice provides general and limited information of the IRS’s interpretation regarding methodologies that could be used for the allocation of the interest expense limitation. As a result of the new provision contained in the Tax Cuts and Jobs Act, Entergy recorded a limitation in the first quarter 2018 which did not have a material effect on financial position, results of operations, or cash flows. For a discussion of proceedings commenced or other responses by Entergy’s regulators to the Tax Cuts and Jobs Act, see Note 2 to the financial statements herein and in the Form 10-K.
Entergy Arkansas [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. As discussed in the Form 10-K, the Tax Cuts and Jobs Act limits the deduction for net business interest expense in certain circumstances. The limitation does not apply to interest expense allocable to the Utility. In Notice 2018-28 released on April 2, 2018, the IRS announced that it intends to issue proposed regulations that will provide guidance to assist taxpayers in complying with the new interest provisions under the Tax Cuts and Jobs Act. The notice provides general and limited information of the IRS’s interpretation regarding methodologies that could be used for the allocation of the interest expense limitation. As a result of the new provision contained in the Tax Cuts and Jobs Act, Entergy recorded a limitation in the first quarter 2018 which did not have a material effect on financial position, results of operations, or cash flows. For a discussion of proceedings commenced or other responses by Entergy’s regulators to the Tax Cuts and Jobs Act, see Note 2 to the financial statements herein and in the Form 10-K.
Entergy Louisiana [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. As discussed in the Form 10-K, the Tax Cuts and Jobs Act limits the deduction for net business interest expense in certain circumstances. The limitation does not apply to interest expense allocable to the Utility. In Notice 2018-28 released on April 2, 2018, the IRS announced that it intends to issue proposed regulations that will provide guidance to assist taxpayers in complying with the new interest provisions under the Tax Cuts and Jobs Act. The notice provides general and limited information of the IRS’s interpretation regarding methodologies that could be used for the allocation of the interest expense limitation. As a result of the new provision contained in the Tax Cuts and Jobs Act, Entergy recorded a limitation in the first quarter 2018 which did not have a material effect on financial position, results of operations, or cash flows. For a discussion of proceedings commenced or other responses by Entergy’s regulators to the Tax Cuts and Jobs Act, see Note 2 to the financial statements herein and in the Form 10-K.
Entergy Mississippi [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. As discussed in the Form 10-K, the Tax Cuts and Jobs Act limits the deduction for net business interest expense in certain circumstances. The limitation does not apply to interest expense allocable to the Utility. In Notice 2018-28 released on April 2, 2018, the IRS announced that it intends to issue proposed regulations that will provide guidance to assist taxpayers in complying with the new interest provisions under the Tax Cuts and Jobs Act. The notice provides general and limited information of the IRS’s interpretation regarding methodologies that could be used for the allocation of the interest expense limitation. As a result of the new provision contained in the Tax Cuts and Jobs Act, Entergy recorded a limitation in the first quarter 2018 which did not have a material effect on financial position, results of operations, or cash flows. For a discussion of proceedings commenced or other responses by Entergy’s regulators to the Tax Cuts and Jobs Act, see Note 2 to the financial statements herein and in the Form 10-K.
Entergy New Orleans [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. As discussed in the Form 10-K, the Tax Cuts and Jobs Act limits the deduction for net business interest expense in certain circumstances. The limitation does not apply to interest expense allocable to the Utility. In Notice 2018-28 released on April 2, 2018, the IRS announced that it intends to issue proposed regulations that will provide guidance to assist taxpayers in complying with the new interest provisions under the Tax Cuts and Jobs Act. The notice provides general and limited information of the IRS’s interpretation regarding methodologies that could be used for the allocation of the interest expense limitation. As a result of the new provision contained in the Tax Cuts and Jobs Act, Entergy recorded a limitation in the first quarter 2018 which did not have a material effect on financial position, results of operations, or cash flows. For a discussion of proceedings commenced or other responses by Entergy’s regulators to the Tax Cuts and Jobs Act, see Note 2 to the financial statements herein and in the Form 10-K.
Entergy Texas [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. As discussed in the Form 10-K, the Tax Cuts and Jobs Act limits the deduction for net business interest expense in certain circumstances. The limitation does not apply to interest expense allocable to the Utility. In Notice 2018-28 released on April 2, 2018, the IRS announced that it intends to issue proposed regulations that will provide guidance to assist taxpayers in complying with the new interest provisions under the Tax Cuts and Jobs Act. The notice provides general and limited information of the IRS’s interpretation regarding methodologies that could be used for the allocation of the interest expense limitation. As a result of the new provision contained in the Tax Cuts and Jobs Act, Entergy recorded a limitation in the first quarter 2018 which did not have a material effect on financial position, results of operations, or cash flows. For a discussion of proceedings commenced or other responses by Entergy’s regulators to the Tax Cuts and Jobs Act, see Note 2 to the financial statements herein and in the Form 10-K.
System Energy [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. As discussed in the Form 10-K, the Tax Cuts and Jobs Act limits the deduction for net business interest expense in certain circumstances. The limitation does not apply to interest expense allocable to the Utility. In Notice 2018-28 released on April 2, 2018, the IRS announced that it intends to issue proposed regulations that will provide guidance to assist taxpayers in complying with the new interest provisions under the Tax Cuts and Jobs Act. The notice provides general and limited information of the IRS’s interpretation regarding methodologies that could be used for the allocation of the interest expense limitation. As a result of the new provision contained in the Tax Cuts and Jobs Act, Entergy recorded a limitation in the first quarter 2018 which did not have a material effect on financial position, results of operations, or cash flows. For a discussion of proceedings commenced or other responses by Entergy’s regulators to the Tax Cuts and Jobs Act, see Note 2 to the financial statements herein and in the Form 10-K.

Property, Plant, And Equipment

Property, Plant, And Equipment	3 Months Ended
	Mar. 31, 2018
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at March 31, 2018 are $280 million for Entergy, $39.1 million for Entergy Arkansas, $119.4 million for Entergy Louisiana, $7.5 million for Entergy Mississippi, $5.6 million for Entergy New Orleans, $14.8 million for Entergy Texas, and $41.9 million for System Energy. Construction expenditures included in accounts payable at December 31, 2017 are $368 million for Entergy, $58.8 million for Entergy Arkansas, $160.4 million for Entergy Louisiana, $17.1 million for Entergy Mississippi, $2.5 million for Entergy New Orleans, $32.8 million for Entergy Texas, and $33.9 million for System Energy.
Entergy Arkansas [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at March 31, 2018 are $280 million for Entergy, $39.1 million for Entergy Arkansas, $119.4 million for Entergy Louisiana, $7.5 million for Entergy Mississippi, $5.6 million for Entergy New Orleans, $14.8 million for Entergy Texas, and $41.9 million for System Energy. Construction expenditures included in accounts payable at December 31, 2017 are $368 million for Entergy, $58.8 million for Entergy Arkansas, $160.4 million for Entergy Louisiana, $17.1 million for Entergy Mississippi, $2.5 million for Entergy New Orleans, $32.8 million for Entergy Texas, and $33.9 million for System Energy.
Entergy Louisiana [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at March 31, 2018 are $280 million for Entergy, $39.1 million for Entergy Arkansas, $119.4 million for Entergy Louisiana, $7.5 million for Entergy Mississippi, $5.6 million for Entergy New Orleans, $14.8 million for Entergy Texas, and $41.9 million for System Energy. Construction expenditures included in accounts payable at December 31, 2017 are $368 million for Entergy, $58.8 million for Entergy Arkansas, $160.4 million for Entergy Louisiana, $17.1 million for Entergy Mississippi, $2.5 million for Entergy New Orleans, $32.8 million for Entergy Texas, and $33.9 million for System Energy.
Entergy Mississippi [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at March 31, 2018 are $280 million for Entergy, $39.1 million for Entergy Arkansas, $119.4 million for Entergy Louisiana, $7.5 million for Entergy Mississippi, $5.6 million for Entergy New Orleans, $14.8 million for Entergy Texas, and $41.9 million for System Energy. Construction expenditures included in accounts payable at December 31, 2017 are $368 million for Entergy, $58.8 million for Entergy Arkansas, $160.4 million for Entergy Louisiana, $17.1 million for Entergy Mississippi, $2.5 million for Entergy New Orleans, $32.8 million for Entergy Texas, and $33.9 million for System Energy.
Entergy New Orleans [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at March 31, 2018 are $280 million for Entergy, $39.1 million for Entergy Arkansas, $119.4 million for Entergy Louisiana, $7.5 million for Entergy Mississippi, $5.6 million for Entergy New Orleans, $14.8 million for Entergy Texas, and $41.9 million for System Energy. Construction expenditures included in accounts payable at December 31, 2017 are $368 million for Entergy, $58.8 million for Entergy Arkansas, $160.4 million for Entergy Louisiana, $17.1 million for Entergy Mississippi, $2.5 million for Entergy New Orleans, $32.8 million for Entergy Texas, and $33.9 million for System Energy.
Entergy Texas [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at March 31, 2018 are $280 million for Entergy, $39.1 million for Entergy Arkansas, $119.4 million for Entergy Louisiana, $7.5 million for Entergy Mississippi, $5.6 million for Entergy New Orleans, $14.8 million for Entergy Texas, and $41.9 million for System Energy. Construction expenditures included in accounts payable at December 31, 2017 are $368 million for Entergy, $58.8 million for Entergy Arkansas, $160.4 million for Entergy Louisiana, $17.1 million for Entergy Mississippi, $2.5 million for Entergy New Orleans, $32.8 million for Entergy Texas, and $33.9 million for System Energy.
System Energy [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at March 31, 2018 are $280 million for Entergy, $39.1 million for Entergy Arkansas, $119.4 million for Entergy Louisiana, $7.5 million for Entergy Mississippi, $5.6 million for Entergy New Orleans, $14.8 million for Entergy Texas, and $41.9 million for System Energy. Construction expenditures included in accounts payable at December 31, 2017 are $368 million for Entergy, $58.8 million for Entergy Arkansas, $160.4 million for Entergy Louisiana, $17.1 million for Entergy Mississippi, $2.5 million for Entergy New Orleans, $32.8 million for Entergy Texas, and $33.9 million for System Energy.

Variable Interest Entities

Variable Interest Entities	3 Months Ended
	Mar. 31, 2018
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments on its lease, including interest, of $8.6 million in the three months ended March 31, 2018 and $8.6 million in the three months ended March 31, 2017 .
Entergy Arkansas [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments on its lease, including interest, of $8.6 million in the three months ended March 31, 2018 and $8.6 million in the three months ended March 31, 2017 .
Entergy Louisiana [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments on its lease, including interest, of $8.6 million in the three months ended March 31, 2018 and $8.6 million in the three months ended March 31, 2017 .
Entergy Mississippi [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments on its lease, including interest, of $8.6 million in the three months ended March 31, 2018 and $8.6 million in the three months ended March 31, 2017 .
Entergy New Orleans [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments on its lease, including interest, of $8.6 million in the three months ended March 31, 2018 and $8.6 million in the three months ended March 31, 2017 .
Entergy Texas [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments on its lease, including interest, of $8.6 million in the three months ended March 31, 2018 and $8.6 million in the three months ended March 31, 2017 .
System Energy [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments on its lease, including interest, of $8.6 million in the three months ended March 31, 2018 and $8.6 million in the three months ended March 31, 2017 .

Revenue Recognition

Revenue Recognition	3 Months Ended
	Mar. 31, 2018
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenue Recognition Entergy implemented ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” effective January 1, 2018. Topic 606 requires entities to “recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.” The ASU details a five-step model that should be followed to achieve the core principle. This accounting was applied to all contracts using the modified retrospective method, which requires an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date. Because the standard did not result in any material change in how Entergy recognizes revenue, however, no adjustment to retained earnings was required. Similarly, there was no effect on revenues recognized under Topic 606 for the three months ended March 31, 2018. Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the three months ended March 31, 2018 were as follows: 2018 (In Thousands) Utility: Residential $892,085 Commercial 595,720 Industrial 597,186 Governmental 56,478 Total billed retail 2,141,469 Sales for resale (a) 69,526 Other electric revenues (b) 27,433 Non-customer revenues (c) 9,834 Total electric revenues 2,248,262 Natural gas 56,695 Entergy Wholesale Commodities: Competitive businesses sales (a) 409,135 Non-customer revenues (c) 9,789 Total competitive businesses 418,924 Total operating revenues $2,723,881 The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $235,524 $295,517 $148,342 $64,575 $148,126 Commercial 120,634 224,928 110,460 54,272 85,427 Industrial 111,477 352,336 42,501 7,570 83,302 Governmental 4,648 17,310 10,848 17,691 5,981 Total billed retail 472,283 890,091 312,151 144,108 322,836 Sales for resale (a) 66,103 89,255 1,993 13,337 23,361 Other electric revenues (b) 10,024 20,503 (719 ) (3,111 ) 2,264 Non-customer revenues (c) 2,614 5,257 2,318 1,484 479 Total electric revenues 551,024 1,005,106 315,743 155,818 348,940 Natural gas — 24,238 — 32,457 — Total operating revenues $551,024 $1,029,344 $315,743 $188,275 $348,940 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Energy is provided on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. This may result in variability of reported revenues from one period to the next as prior estimates are reversed and new estimates recorded. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as non-customer revenue in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and the City of New Orleans, including Algiers, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities revenues are from Entergy’s nuclear power plants located in the northern United States. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Most of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in 2022. The PPA prices are for a set price per MWh and escalate each year, up to $61.50 /MWh in 2022. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. Additionally, as the PPA pricing was considered below-market at the time of acquisition, a liability was recorded for the fair value of the below-market PPA, and is being amortized to revenue over the life of the agreement. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues.
Entergy Arkansas [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenue Recognition Entergy implemented ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” effective January 1, 2018. Topic 606 requires entities to “recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.” The ASU details a five-step model that should be followed to achieve the core principle. This accounting was applied to all contracts using the modified retrospective method, which requires an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date. Because the standard did not result in any material change in how Entergy recognizes revenue, however, no adjustment to retained earnings was required. Similarly, there was no effect on revenues recognized under Topic 606 for the three months ended March 31, 2018. Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the three months ended March 31, 2018 were as follows: 2018 (In Thousands) Utility: Residential $892,085 Commercial 595,720 Industrial 597,186 Governmental 56,478 Total billed retail 2,141,469 Sales for resale (a) 69,526 Other electric revenues (b) 27,433 Non-customer revenues (c) 9,834 Total electric revenues 2,248,262 Natural gas 56,695 Entergy Wholesale Commodities: Competitive businesses sales (a) 409,135 Non-customer revenues (c) 9,789 Total competitive businesses 418,924 Total operating revenues $2,723,881 The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $235,524 $295,517 $148,342 $64,575 $148,126 Commercial 120,634 224,928 110,460 54,272 85,427 Industrial 111,477 352,336 42,501 7,570 83,302 Governmental 4,648 17,310 10,848 17,691 5,981 Total billed retail 472,283 890,091 312,151 144,108 322,836 Sales for resale (a) 66,103 89,255 1,993 13,337 23,361 Other electric revenues (b) 10,024 20,503 (719 ) (3,111 ) 2,264 Non-customer revenues (c) 2,614 5,257 2,318 1,484 479 Total electric revenues 551,024 1,005,106 315,743 155,818 348,940 Natural gas — 24,238 — 32,457 — Total operating revenues $551,024 $1,029,344 $315,743 $188,275 $348,940 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Energy is provided on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. This may result in variability of reported revenues from one period to the next as prior estimates are reversed and new estimates recorded. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as non-customer revenue in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and the City of New Orleans, including Algiers, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities revenues are from Entergy’s nuclear power plants located in the northern United States. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Most of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in 2022. The PPA prices are for a set price per MWh and escalate each year, up to $61.50 /MWh in 2022. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. Additionally, as the PPA pricing was considered below-market at the time of acquisition, a liability was recorded for the fair value of the below-market PPA, and is being amortized to revenue over the life of the agreement. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues.
Entergy Louisiana [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenue Recognition Entergy implemented ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” effective January 1, 2018. Topic 606 requires entities to “recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.” The ASU details a five-step model that should be followed to achieve the core principle. This accounting was applied to all contracts using the modified retrospective method, which requires an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date. Because the standard did not result in any material change in how Entergy recognizes revenue, however, no adjustment to retained earnings was required. Similarly, there was no effect on revenues recognized under Topic 606 for the three months ended March 31, 2018. Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the three months ended March 31, 2018 were as follows: 2018 (In Thousands) Utility: Residential $892,085 Commercial 595,720 Industrial 597,186 Governmental 56,478 Total billed retail 2,141,469 Sales for resale (a) 69,526 Other electric revenues (b) 27,433 Non-customer revenues (c) 9,834 Total electric revenues 2,248,262 Natural gas 56,695 Entergy Wholesale Commodities: Competitive businesses sales (a) 409,135 Non-customer revenues (c) 9,789 Total competitive businesses 418,924 Total operating revenues $2,723,881 The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $235,524 $295,517 $148,342 $64,575 $148,126 Commercial 120,634 224,928 110,460 54,272 85,427 Industrial 111,477 352,336 42,501 7,570 83,302 Governmental 4,648 17,310 10,848 17,691 5,981 Total billed retail 472,283 890,091 312,151 144,108 322,836 Sales for resale (a) 66,103 89,255 1,993 13,337 23,361 Other electric revenues (b) 10,024 20,503 (719 ) (3,111 ) 2,264 Non-customer revenues (c) 2,614 5,257 2,318 1,484 479 Total electric revenues 551,024 1,005,106 315,743 155,818 348,940 Natural gas — 24,238 — 32,457 — Total operating revenues $551,024 $1,029,344 $315,743 $188,275 $348,940 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Energy is provided on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. This may result in variability of reported revenues from one period to the next as prior estimates are reversed and new estimates recorded. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as non-customer revenue in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and the City of New Orleans, including Algiers, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities revenues are from Entergy’s nuclear power plants located in the northern United States. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Most of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in 2022. The PPA prices are for a set price per MWh and escalate each year, up to $61.50 /MWh in 2022. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. Additionally, as the PPA pricing was considered below-market at the time of acquisition, a liability was recorded for the fair value of the below-market PPA, and is being amortized to revenue over the life of the agreement. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues.
Entergy Mississippi [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenue Recognition Entergy implemented ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” effective January 1, 2018. Topic 606 requires entities to “recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.” The ASU details a five-step model that should be followed to achieve the core principle. This accounting was applied to all contracts using the modified retrospective method, which requires an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date. Because the standard did not result in any material change in how Entergy recognizes revenue, however, no adjustment to retained earnings was required. Similarly, there was no effect on revenues recognized under Topic 606 for the three months ended March 31, 2018. Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the three months ended March 31, 2018 were as follows: 2018 (In Thousands) Utility: Residential $892,085 Commercial 595,720 Industrial 597,186 Governmental 56,478 Total billed retail 2,141,469 Sales for resale (a) 69,526 Other electric revenues (b) 27,433 Non-customer revenues (c) 9,834 Total electric revenues 2,248,262 Natural gas 56,695 Entergy Wholesale Commodities: Competitive businesses sales (a) 409,135 Non-customer revenues (c) 9,789 Total competitive businesses 418,924 Total operating revenues $2,723,881 The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $235,524 $295,517 $148,342 $64,575 $148,126 Commercial 120,634 224,928 110,460 54,272 85,427 Industrial 111,477 352,336 42,501 7,570 83,302 Governmental 4,648 17,310 10,848 17,691 5,981 Total billed retail 472,283 890,091 312,151 144,108 322,836 Sales for resale (a) 66,103 89,255 1,993 13,337 23,361 Other electric revenues (b) 10,024 20,503 (719 ) (3,111 ) 2,264 Non-customer revenues (c) 2,614 5,257 2,318 1,484 479 Total electric revenues 551,024 1,005,106 315,743 155,818 348,940 Natural gas — 24,238 — 32,457 — Total operating revenues $551,024 $1,029,344 $315,743 $188,275 $348,940 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Energy is provided on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. This may result in variability of reported revenues from one period to the next as prior estimates are reversed and new estimates recorded. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as non-customer revenue in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and the City of New Orleans, including Algiers, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities revenues are from Entergy’s nuclear power plants located in the northern United States. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Most of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in 2022. The PPA prices are for a set price per MWh and escalate each year, up to $61.50 /MWh in 2022. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. Additionally, as the PPA pricing was considered below-market at the time of acquisition, a liability was recorded for the fair value of the below-market PPA, and is being amortized to revenue over the life of the agreement. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues.
Entergy New Orleans [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenue Recognition Entergy implemented ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” effective January 1, 2018. Topic 606 requires entities to “recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.” The ASU details a five-step model that should be followed to achieve the core principle. This accounting was applied to all contracts using the modified retrospective method, which requires an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date. Because the standard did not result in any material change in how Entergy recognizes revenue, however, no adjustment to retained earnings was required. Similarly, there was no effect on revenues recognized under Topic 606 for the three months ended March 31, 2018. Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the three months ended March 31, 2018 were as follows: 2018 (In Thousands) Utility: Residential $892,085 Commercial 595,720 Industrial 597,186 Governmental 56,478 Total billed retail 2,141,469 Sales for resale (a) 69,526 Other electric revenues (b) 27,433 Non-customer revenues (c) 9,834 Total electric revenues 2,248,262 Natural gas 56,695 Entergy Wholesale Commodities: Competitive businesses sales (a) 409,135 Non-customer revenues (c) 9,789 Total competitive businesses 418,924 Total operating revenues $2,723,881 The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $235,524 $295,517 $148,342 $64,575 $148,126 Commercial 120,634 224,928 110,460 54,272 85,427 Industrial 111,477 352,336 42,501 7,570 83,302 Governmental 4,648 17,310 10,848 17,691 5,981 Total billed retail 472,283 890,091 312,151 144,108 322,836 Sales for resale (a) 66,103 89,255 1,993 13,337 23,361 Other electric revenues (b) 10,024 20,503 (719 ) (3,111 ) 2,264 Non-customer revenues (c) 2,614 5,257 2,318 1,484 479 Total electric revenues 551,024 1,005,106 315,743 155,818 348,940 Natural gas — 24,238 — 32,457 — Total operating revenues $551,024 $1,029,344 $315,743 $188,275 $348,940 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Energy is provided on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. This may result in variability of reported revenues from one period to the next as prior estimates are reversed and new estimates recorded. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as non-customer revenue in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and the City of New Orleans, including Algiers, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities revenues are from Entergy’s nuclear power plants located in the northern United States. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Most of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in 2022. The PPA prices are for a set price per MWh and escalate each year, up to $61.50 /MWh in 2022. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. Additionally, as the PPA pricing was considered below-market at the time of acquisition, a liability was recorded for the fair value of the below-market PPA, and is being amortized to revenue over the life of the agreement. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues.
Entergy Texas [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenue Recognition Entergy implemented ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” effective January 1, 2018. Topic 606 requires entities to “recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.” The ASU details a five-step model that should be followed to achieve the core principle. This accounting was applied to all contracts using the modified retrospective method, which requires an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date. Because the standard did not result in any material change in how Entergy recognizes revenue, however, no adjustment to retained earnings was required. Similarly, there was no effect on revenues recognized under Topic 606 for the three months ended March 31, 2018. Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the three months ended March 31, 2018 were as follows: 2018 (In Thousands) Utility: Residential $892,085 Commercial 595,720 Industrial 597,186 Governmental 56,478 Total billed retail 2,141,469 Sales for resale (a) 69,526 Other electric revenues (b) 27,433 Non-customer revenues (c) 9,834 Total electric revenues 2,248,262 Natural gas 56,695 Entergy Wholesale Commodities: Competitive businesses sales (a) 409,135 Non-customer revenues (c) 9,789 Total competitive businesses 418,924 Total operating revenues $2,723,881 The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $235,524 $295,517 $148,342 $64,575 $148,126 Commercial 120,634 224,928 110,460 54,272 85,427 Industrial 111,477 352,336 42,501 7,570 83,302 Governmental 4,648 17,310 10,848 17,691 5,981 Total billed retail 472,283 890,091 312,151 144,108 322,836 Sales for resale (a) 66,103 89,255 1,993 13,337 23,361 Other electric revenues (b) 10,024 20,503 (719 ) (3,111 ) 2,264 Non-customer revenues (c) 2,614 5,257 2,318 1,484 479 Total electric revenues 551,024 1,005,106 315,743 155,818 348,940 Natural gas — 24,238 — 32,457 — Total operating revenues $551,024 $1,029,344 $315,743 $188,275 $348,940 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Energy is provided on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. This may result in variability of reported revenues from one period to the next as prior estimates are reversed and new estimates recorded. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as non-customer revenue in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and the City of New Orleans, including Algiers, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities revenues are from Entergy’s nuclear power plants located in the northern United States. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Most of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in 2022. The PPA prices are for a set price per MWh and escalate each year, up to $61.50 /MWh in 2022. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. Additionally, as the PPA pricing was considered below-market at the time of acquisition, a liability was recorded for the fair value of the below-market PPA, and is being amortized to revenue over the life of the agreement. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues.
System Energy [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenue Recognition Entergy implemented ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” effective January 1, 2018. Topic 606 requires entities to “recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.” The ASU details a five-step model that should be followed to achieve the core principle. This accounting was applied to all contracts using the modified retrospective method, which requires an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date. Because the standard did not result in any material change in how Entergy recognizes revenue, however, no adjustment to retained earnings was required. Similarly, there was no effect on revenues recognized under Topic 606 for the three months ended March 31, 2018. Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the three months ended March 31, 2018 were as follows: 2018 (In Thousands) Utility: Residential $892,085 Commercial 595,720 Industrial 597,186 Governmental 56,478 Total billed retail 2,141,469 Sales for resale (a) 69,526 Other electric revenues (b) 27,433 Non-customer revenues (c) 9,834 Total electric revenues 2,248,262 Natural gas 56,695 Entergy Wholesale Commodities: Competitive businesses sales (a) 409,135 Non-customer revenues (c) 9,789 Total competitive businesses 418,924 Total operating revenues $2,723,881 The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $235,524 $295,517 $148,342 $64,575 $148,126 Commercial 120,634 224,928 110,460 54,272 85,427 Industrial 111,477 352,336 42,501 7,570 83,302 Governmental 4,648 17,310 10,848 17,691 5,981 Total billed retail 472,283 890,091 312,151 144,108 322,836 Sales for resale (a) 66,103 89,255 1,993 13,337 23,361 Other electric revenues (b) 10,024 20,503 (719 ) (3,111 ) 2,264 Non-customer revenues (c) 2,614 5,257 2,318 1,484 479 Total electric revenues 551,024 1,005,106 315,743 155,818 348,940 Natural gas — 24,238 — 32,457 — Total operating revenues $551,024 $1,029,344 $315,743 $188,275 $348,940 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Energy is provided on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. This may result in variability of reported revenues from one period to the next as prior estimates are reversed and new estimates recorded. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as non-customer revenue in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and the City of New Orleans, including Algiers, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities revenues are from Entergy’s nuclear power plants located in the northern United States. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Most of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in 2022. The PPA prices are for a set price per MWh and escalate each year, up to $61.50 /MWh in 2022. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. Additionally, as the PPA pricing was considered below-market at the time of acquisition, a liability was recorded for the fair value of the below-market PPA, and is being amortized to revenue over the life of the agreement. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues.

Asset Retirement Obligations As

Asset Retirement Obligations Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2018
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. Following are updates to that discussion. In the first quarter 2018, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in an $85.4 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining life of the unit.
Entergy Arkansas [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. Following are updates to that discussion. In the first quarter 2018, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in an $85.4 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining life of the unit.
Entergy Louisiana [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. Following are updates to that discussion. In the first quarter 2018, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in an $85.4 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining life of the unit.
Entergy Mississippi [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. Following are updates to that discussion. In the first quarter 2018, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in an $85.4 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining life of the unit.
Entergy New Orleans [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. Following are updates to that discussion. In the first quarter 2018, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in an $85.4 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining life of the unit.
Entergy Texas [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. Following are updates to that discussion. In the first quarter 2018, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in an $85.4 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining life of the unit.
System Energy [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. Following are updates to that discussion. In the first quarter 2018, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in an $85.4 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining life of the unit.

Rate And Regulatory Matters Rat

Rate And Regulatory Matters Rate and Regulatory Matters (Tables)	3 Months Ended
	Mar. 31, 2018
Entergy Arkansas [Member]
Estimate Of Payments Or Receipts Among Utility Operating Companies [Table Text Block]	Payments (Receipts) (In Millions) Entergy Arkansas $6 Entergy New Orleans $2 Entergy Texas ($8)
Entergy New Orleans [Member]
Estimate Of Payments Or Receipts Among Utility Operating Companies [Table Text Block]	Payments (Receipts) (In Millions) Entergy Arkansas $6 Entergy New Orleans $2 Entergy Texas ($8)
Entergy Texas [Member]
Estimate Of Payments Or Receipts Among Utility Operating Companies [Table Text Block]	Payments (Receipts) (In Millions) Entergy Arkansas $6 Entergy New Orleans $2 Entergy Texas ($8)

Equity (Tables)

Equity (Tables)	3 Months Ended
	Mar. 31, 2018
Schedule Of Earnings Per Share Basic And Diluted	The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Three Months Ended March 31, 2018 2017 (In Millions, Except Per Share Data) Basic earnings per share Income Shares $/share Income Shares $/share Net income attributable to Entergy Corporation $132.8 180.7 $0.73 $82.6 179.3 $0.46 Average dilutive effect of: Stock options 0.2 — 0.1 — Other equity plans 0.5 — 0.4 — Diluted earnings per share $132.8 181.4 $0.73 $82.6 179.8 $0.46
Schedule of Accumulated Other Comprehensive Income (Loss)	Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 2018 by component: Cash flow hedges net unrealized gain (loss) Pension and other postretirement liabilities Net unrealized investment gain (loss) Total Accumulated Other Comprehensive Income (Loss) (In Thousands) Ending balance, December 31, 2017 ($37,477 ) ($531,099 ) $545,045 ($23,531 ) Implementation of accounting standards — — (632,617 ) (632,617 ) Beginning balance, January 1, 2018 ($37,477 ) ($531,099 ) ($87,572 ) ($656,148 ) Other comprehensive income (loss) before reclassifications 71,566 — 838 72,404 Amounts reclassified from accumulated other comprehensive income (loss) 23,861 16,574 (33,694 ) 6,741 Net other comprehensive income (loss) for the period 95,427 16,574 (32,856 ) 79,145 Reclassification pursuant to ASU 2018-02 (7,756 ) (90,966 ) 114,227 15,505 Ending balance, March 31, 2018 $50,194 ($605,491 ) ($6,201 ) ($561,498 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended March 31, 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 32,608 — 39,872 — 72,480 Amounts reclassified from accumulated other comprehensive income (loss) (33,136 ) 8,632 (2,045 ) — (26,549 ) Net other comprehensive income (loss) for the period (528 ) 8,632 37,827 — 45,931 Ending balance, March 31, 2017 $3,465 ($460,814 ) $467,561 $748 $10,960
Reclassification out of Accumulated Other Comprehensive Income	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended March 31, 2018 and 2017 are as follows: Amounts reclassified Income Statement Location 2018 2017 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts ($30,082 ) $51,227 Competitive business operating revenues Interest rate swaps (122 ) (250 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges (30,204 ) 50,977 6,343 (17,841 ) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) ($23,861 ) $33,136 Pension and other postretirement liabilities Amortization of prior-service credit $5,426 $6,562 (a) Amortization of loss (24,952 ) (21,571 ) (a) Settlement loss (1,616 ) — (a) Total amortization (21,142 ) (15,009 ) 4,568 6,377 Income taxes Total amortization (net of tax) ($16,574 ) ($8,632 ) Net unrealized investment gain (loss) Realized gain (loss) $53,314 $4,010 Interest and investment income (19,620 ) (1,965 ) Income taxes Total realized investment gain (loss) (net of tax) $33,694 $2,045 Total reclassifications for the period (net of tax) ($6,741 ) $26,549 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.
Entergy Louisiana [Member]
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended March 31, 2018 and 2017: Pension and Other 2018 2017 (In Thousands) Beginning balance, January 1, ($46,400 ) ($48,442 ) Amounts reclassified from accumulated other (501 ) (370 ) Net other comprehensive income (loss) for the period (501 ) (370 ) Reclassification pursuant to ASU 2018-02 (10,049 ) — Ending balance, March 31, ($56,950 ) ($48,812 )
Reclassification out of Accumulated Other Comprehensive Income	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended March 31, 2018 and 2017 are as follows: Amounts reclassified Income Statement Location 2018 2017 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,934 $1,934 (a) Amortization of loss (1,257 ) (1,332 ) (a) Total amortization 677 602 (176 ) (232 ) Income taxes Total amortization (net of tax) 501 370 Total reclassifications for the period (net of tax) $501 $370 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.

Revolving Credit Facilities, 26

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Tables)	3 Months Ended
	Mar. 31, 2018
Summary Of The Borrowings Outstanding And Capacity Available Under The Facility	Following is a summary of the borrowings outstanding and capacity available under the facility as of March 31, 2018 . Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $1,125 $6 $2,369
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2018 Letters of Credit Outstanding as of March 31, 2018 Entergy Arkansas April 2018 $20 million (b) 3.14% $— $— Entergy Arkansas August 2022 $150 million (c) 3.12% $50 million $— Entergy Louisiana August 2022 $350 million (c) 2.94% $100 million $9.1 million Entergy Mississippi May 2018 $37.5 million (d) 3.39% $— $— Entergy Mississippi May 2018 $35 million (d) 3.39% $— $— Entergy Mississippi May 2018 $20 million (d) 3.39% $— $— Entergy Mississippi May 2018 $10 million (d) 3.39% $— $— Entergy New Orleans November 2018 $25 million (c) 3.36% $— $0.8 million Entergy Texas August 2022 $150 million (c) 3.39% $— $24.4 million (a) For credit facilities with no borrowings as of March 31, 2018, the interest rate is the estimated interest rate as of March 31, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. In April 2018, Entergy Arkansas renewed its credit facility through April 2019. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. Entergy Mississippi expects to renew its credit facilities prior to expiration.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $23.8 million Entergy Mississippi $40 million 0.70% $16.6 million Entergy New Orleans $15 million 1.00% $4.8 million Entergy Texas $50 million 0.70% $25.6 million (a) As of March 31, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2018 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $124 Entergy Louisiana $450 $— Entergy Mississippi $175 $75 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of March 31, 2018 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 3.74% $43.9 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.82% $52.3 Entergy Louisiana Waterford VIE May 2019 $85 3.35% $62.9 (b) System Energy VIE May 2019 $120 3.46% $43.2 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) The total amount outstanding as of March 31, 2018 is commercial paper, and is classified as a current liability.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of March 31, 2018 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million System Energy VIE 3.42% Series J due April 2021 $100 million
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,851,636 $16,771,585 Entergy Arkansas $2,978,569 $2,812,019 Entergy Louisiana $6,938,439 $7,022,323 Entergy Mississippi $1,270,399 $1,252,877 Entergy New Orleans $436,995 $446,981 Entergy Texas $1,562,555 $1,603,892 System Energy $601,582 $576,121 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $184 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Arkansas [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2018 Letters of Credit Outstanding as of March 31, 2018 Entergy Arkansas April 2018 $20 million (b) 3.14% $— $— Entergy Arkansas August 2022 $150 million (c) 3.12% $50 million $— Entergy Louisiana August 2022 $350 million (c) 2.94% $100 million $9.1 million Entergy Mississippi May 2018 $37.5 million (d) 3.39% $— $— Entergy Mississippi May 2018 $35 million (d) 3.39% $— $— Entergy Mississippi May 2018 $20 million (d) 3.39% $— $— Entergy Mississippi May 2018 $10 million (d) 3.39% $— $— Entergy New Orleans November 2018 $25 million (c) 3.36% $— $0.8 million Entergy Texas August 2022 $150 million (c) 3.39% $— $24.4 million (a) For credit facilities with no borrowings as of March 31, 2018, the interest rate is the estimated interest rate as of March 31, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. In April 2018, Entergy Arkansas renewed its credit facility through April 2019. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. Entergy Mississippi expects to renew its credit facilities prior to expiration.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $23.8 million Entergy Mississippi $40 million 0.70% $16.6 million Entergy New Orleans $15 million 1.00% $4.8 million Entergy Texas $50 million 0.70% $25.6 million (a) As of March 31, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2018 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $124 Entergy Louisiana $450 $— Entergy Mississippi $175 $75 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of March 31, 2018 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 3.74% $43.9 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.82% $52.3 Entergy Louisiana Waterford VIE May 2019 $85 3.35% $62.9 (b) System Energy VIE May 2019 $120 3.46% $43.2 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) The total amount outstanding as of March 31, 2018 is commercial paper, and is classified as a current liability.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of March 31, 2018 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million System Energy VIE 3.42% Series J due April 2021 $100 million
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,851,636 $16,771,585 Entergy Arkansas $2,978,569 $2,812,019 Entergy Louisiana $6,938,439 $7,022,323 Entergy Mississippi $1,270,399 $1,252,877 Entergy New Orleans $436,995 $446,981 Entergy Texas $1,562,555 $1,603,892 System Energy $601,582 $576,121 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $184 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Louisiana [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2018 Letters of Credit Outstanding as of March 31, 2018 Entergy Arkansas April 2018 $20 million (b) 3.14% $— $— Entergy Arkansas August 2022 $150 million (c) 3.12% $50 million $— Entergy Louisiana August 2022 $350 million (c) 2.94% $100 million $9.1 million Entergy Mississippi May 2018 $37.5 million (d) 3.39% $— $— Entergy Mississippi May 2018 $35 million (d) 3.39% $— $— Entergy Mississippi May 2018 $20 million (d) 3.39% $— $— Entergy Mississippi May 2018 $10 million (d) 3.39% $— $— Entergy New Orleans November 2018 $25 million (c) 3.36% $— $0.8 million Entergy Texas August 2022 $150 million (c) 3.39% $— $24.4 million (a) For credit facilities with no borrowings as of March 31, 2018, the interest rate is the estimated interest rate as of March 31, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. In April 2018, Entergy Arkansas renewed its credit facility through April 2019. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. Entergy Mississippi expects to renew its credit facilities prior to expiration.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $23.8 million Entergy Mississippi $40 million 0.70% $16.6 million Entergy New Orleans $15 million 1.00% $4.8 million Entergy Texas $50 million 0.70% $25.6 million (a) As of March 31, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2018 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $124 Entergy Louisiana $450 $— Entergy Mississippi $175 $75 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of March 31, 2018 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 3.74% $43.9 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.82% $52.3 Entergy Louisiana Waterford VIE May 2019 $85 3.35% $62.9 (b) System Energy VIE May 2019 $120 3.46% $43.2 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) The total amount outstanding as of March 31, 2018 is commercial paper, and is classified as a current liability.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of March 31, 2018 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million System Energy VIE 3.42% Series J due April 2021 $100 million
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,851,636 $16,771,585 Entergy Arkansas $2,978,569 $2,812,019 Entergy Louisiana $6,938,439 $7,022,323 Entergy Mississippi $1,270,399 $1,252,877 Entergy New Orleans $436,995 $446,981 Entergy Texas $1,562,555 $1,603,892 System Energy $601,582 $576,121 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $184 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Mississippi [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2018 Letters of Credit Outstanding as of March 31, 2018 Entergy Arkansas April 2018 $20 million (b) 3.14% $— $— Entergy Arkansas August 2022 $150 million (c) 3.12% $50 million $— Entergy Louisiana August 2022 $350 million (c) 2.94% $100 million $9.1 million Entergy Mississippi May 2018 $37.5 million (d) 3.39% $— $— Entergy Mississippi May 2018 $35 million (d) 3.39% $— $— Entergy Mississippi May 2018 $20 million (d) 3.39% $— $— Entergy Mississippi May 2018 $10 million (d) 3.39% $— $— Entergy New Orleans November 2018 $25 million (c) 3.36% $— $0.8 million Entergy Texas August 2022 $150 million (c) 3.39% $— $24.4 million (a) For credit facilities with no borrowings as of March 31, 2018, the interest rate is the estimated interest rate as of March 31, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. In April 2018, Entergy Arkansas renewed its credit facility through April 2019. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. Entergy Mississippi expects to renew its credit facilities prior to expiration.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $23.8 million Entergy Mississippi $40 million 0.70% $16.6 million Entergy New Orleans $15 million 1.00% $4.8 million Entergy Texas $50 million 0.70% $25.6 million (a) As of March 31, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2018 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $124 Entergy Louisiana $450 $— Entergy Mississippi $175 $75 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,851,636 $16,771,585 Entergy Arkansas $2,978,569 $2,812,019 Entergy Louisiana $6,938,439 $7,022,323 Entergy Mississippi $1,270,399 $1,252,877 Entergy New Orleans $436,995 $446,981 Entergy Texas $1,562,555 $1,603,892 System Energy $601,582 $576,121 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $184 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy New Orleans [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2018 Letters of Credit Outstanding as of March 31, 2018 Entergy Arkansas April 2018 $20 million (b) 3.14% $— $— Entergy Arkansas August 2022 $150 million (c) 3.12% $50 million $— Entergy Louisiana August 2022 $350 million (c) 2.94% $100 million $9.1 million Entergy Mississippi May 2018 $37.5 million (d) 3.39% $— $— Entergy Mississippi May 2018 $35 million (d) 3.39% $— $— Entergy Mississippi May 2018 $20 million (d) 3.39% $— $— Entergy Mississippi May 2018 $10 million (d) 3.39% $— $— Entergy New Orleans November 2018 $25 million (c) 3.36% $— $0.8 million Entergy Texas August 2022 $150 million (c) 3.39% $— $24.4 million (a) For credit facilities with no borrowings as of March 31, 2018, the interest rate is the estimated interest rate as of March 31, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. In April 2018, Entergy Arkansas renewed its credit facility through April 2019. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. Entergy Mississippi expects to renew its credit facilities prior to expiration.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $23.8 million Entergy Mississippi $40 million 0.70% $16.6 million Entergy New Orleans $15 million 1.00% $4.8 million Entergy Texas $50 million 0.70% $25.6 million (a) As of March 31, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2018 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $124 Entergy Louisiana $450 $— Entergy Mississippi $175 $75 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,851,636 $16,771,585 Entergy Arkansas $2,978,569 $2,812,019 Entergy Louisiana $6,938,439 $7,022,323 Entergy Mississippi $1,270,399 $1,252,877 Entergy New Orleans $436,995 $446,981 Entergy Texas $1,562,555 $1,603,892 System Energy $601,582 $576,121 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $184 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Texas [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of March 31, 2018 Letters of Credit Outstanding as of March 31, 2018 Entergy Arkansas April 2018 $20 million (b) 3.14% $— $— Entergy Arkansas August 2022 $150 million (c) 3.12% $50 million $— Entergy Louisiana August 2022 $350 million (c) 2.94% $100 million $9.1 million Entergy Mississippi May 2018 $37.5 million (d) 3.39% $— $— Entergy Mississippi May 2018 $35 million (d) 3.39% $— $— Entergy Mississippi May 2018 $20 million (d) 3.39% $— $— Entergy Mississippi May 2018 $10 million (d) 3.39% $— $— Entergy New Orleans November 2018 $25 million (c) 3.36% $— $0.8 million Entergy Texas August 2022 $150 million (c) 3.39% $— $24.4 million (a) For credit facilities with no borrowings as of March 31, 2018, the interest rate is the estimated interest rate as of March 31, 2018 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. In April 2018, Entergy Arkansas renewed its credit facility through April 2019. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. Entergy Mississippi expects to renew its credit facilities prior to expiration.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of March 31, 2018 : Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of March 31, 2018 (a) Entergy Arkansas $25 million 0.70% $1 million Entergy Louisiana $125 million 0.70% $23.8 million Entergy Mississippi $40 million 0.70% $16.6 million Entergy New Orleans $15 million 1.00% $4.8 million Entergy Texas $50 million 0.70% $25.6 million (a) As of March 31, 2018 , letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2018 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $124 Entergy Louisiana $450 $— Entergy Mississippi $175 $75 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,851,636 $16,771,585 Entergy Arkansas $2,978,569 $2,812,019 Entergy Louisiana $6,938,439 $7,022,323 Entergy Mississippi $1,270,399 $1,252,877 Entergy New Orleans $436,995 $446,981 Entergy Texas $1,562,555 $1,603,892 System Energy $601,582 $576,121 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $184 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
System Energy [Member]
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of March 31, 2018 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $124 Entergy Louisiana $450 $— Entergy Mississippi $175 $75 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issued commercial paper as of March 31, 2018 as follows: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of March 31, 2018 (Dollars in Millions) Entergy Arkansas VIE May 2019 $80 3.74% $43.9 (b) Entergy Louisiana River Bend VIE May 2019 $105 2.82% $52.3 Entergy Louisiana Waterford VIE May 2019 $85 3.35% $62.9 (b) System Energy VIE May 2019 $120 3.46% $43.2 (b) (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. (b) The total amount outstanding as of March 31, 2018 is commercial paper, and is classified as a current liability.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of March 31, 2018 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 $90 million Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Louisiana River Bend VIE 3.38% Series R due August 2020 $70 million Entergy Louisiana Waterford VIE 3.92% Series H due February 2021 $40 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 3.78% Series I due October 2018 $85 million System Energy VIE 3.42% Series J due April 2021 $100 million
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of March 31, 2018 are as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $16,851,636 $16,771,585 Entergy Arkansas $2,978,569 $2,812,019 Entergy Louisiana $6,938,439 $7,022,323 Entergy Mississippi $1,270,399 $1,252,877 Entergy New Orleans $436,995 $446,981 Entergy Texas $1,562,555 $1,603,892 System Energy $601,582 $576,121 (a) The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $184 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2017 were as follows: Book Value of Long-Term Debt Fair Value of Long-Term Debt (a) (b) (In Thousands) Entergy $15,075,266 $15,367,453 Entergy Arkansas $2,952,399 $2,865,844 Entergy Louisiana $6,144,071 $6,389,774 Entergy Mississippi $1,270,122 $1,285,741 Entergy New Orleans $436,870 $455,968 Entergy Texas $1,587,150 $1,661,902 System Energy $551,488 $529,119 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2018
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Financial Information For Stock Options	The following table includes financial information for outstanding stock options for the three months ended March 31, 2018 and 2017 : 2018 2017 (In Millions) Compensation expense included in Entergy’s net income $1.1 $1.1 Tax benefit recognized in Entergy’s net income $0.3 $0.4 Compensation cost capitalized as part of fixed assets and inventory $0.2 $0.2
Financial Information For Restricted Stock	The following table includes financial information for other outstanding equity awards for the three months ended March 31, 2018 and 2017 : 2018 2017 (In Millions) Compensation expense included in Entergy’s net income $8.8 $8.2 Tax benefit recognized in Entergy’s net income $2.2 $3.1 Compensation cost capitalized as part of fixed assets and inventory $2.3 $2.0

Retirement And Other Postreti28

Retirement And Other Postretirement Benefits (Tables)	3 Months Ended
	Mar. 31, 2018	Mar. 31, 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 first quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($70 ) $5,426 Amortization of loss (21,957 ) (1,932 ) (1,063 ) (24,952 ) Settlement loss — — (1,616 ) (1,616 ) ($22,056 ) $3,663 ($2,749 ) ($21,142 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,717 ($90 ) $6,562 Amortization of loss (18,450 ) (2,202 ) (919 ) (21,571 ) ($18,515 ) $4,515 ($1,009 ) ($15,009 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Entergy’s qualified pension cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $38,752 $33,410 Interest cost on projected benefit obligation 66,854 65,206 Expected return on assets (110,535 ) (102,056 ) Amortization of prior service cost 99 65 Amortization of loss 68,526 56,930 Net pension costs $63,696 $53,555
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Entergy’s other postretirement benefit cost, including amounts capitalized, for the first quarters of 2018 and 2017, included the following components: 2018 2017 (In Thousands) Service cost - benefits earned during the period $6,782 $6,729 Interest cost on accumulated postretirement benefit obligation (APBO) 12,681 13,960 Expected return on assets (10,373 ) (9,408 ) Amortization of prior service credit (9,251 ) (10,356 ) Amortization of loss 3,432 5,476 Net other postretirement benefit cost $3,271 $6,401
Entergy Arkansas [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost		The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projects benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,917 $14,933 $7,250 $10,883 $13,786 Pension contributions made through March 2018 $17,373 $19,510 $4,194 $2,061 $3,873 $3,715 Remaining estimated pension contributions to be made in 2018 $46,689 $52,407 $10,739 $5,189 $7,010 $10,071
Entergy Arkansas [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174
Entergy Arkansas [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $132 $50 $80 $21 $137 2017 $105 $48 $64 $18 $127
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 first quarters of 2018 and 2017: 2018 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($99 ) $5,595 ($70 ) $5,426 Amortization of loss (21,957 ) (1,932 ) (1,063 ) (24,952 ) Settlement loss — — (1,616 ) (1,616 ) ($22,056 ) $3,663 ($2,749 ) ($21,142 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 2017 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost)/credit ($65 ) $6,717 ($90 ) $6,562 Amortization of loss (18,450 ) (2,202 ) (919 ) (21,571 ) ($18,515 ) $4,515 ($1,009 ) ($15,009 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of loss (865 ) (465 ) (2 ) (1,332 ) ($865 ) $1,469 ($2 ) $602
Entergy Louisiana [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projects benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,917 $14,933 $7,250 $10,883 $13,786 Pension contributions made through March 2018 $17,373 $19,510 $4,194 $2,061 $3,873 $3,715 Remaining estimated pension contributions to be made in 2018 $46,689 $52,407 $10,739 $5,189 $7,010 $10,071
Entergy Louisiana [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174
Entergy Louisiana [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $132 $50 $80 $21 $137 2017 $105 $48 $64 $18 $127
Entergy Mississippi [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projects benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,917 $14,933 $7,250 $10,883 $13,786 Pension contributions made through March 2018 $17,373 $19,510 $4,194 $2,061 $3,873 $3,715 Remaining estimated pension contributions to be made in 2018 $46,689 $52,407 $10,739 $5,189 $7,010 $10,071
Entergy Mississippi [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174
Entergy Mississippi [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $132 $50 $80 $21 $137 2017 $105 $48 $64 $18 $127
Entergy New Orleans [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projects benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,917 $14,933 $7,250 $10,883 $13,786 Pension contributions made through March 2018 $17,373 $19,510 $4,194 $2,061 $3,873 $3,715 Remaining estimated pension contributions to be made in 2018 $46,689 $52,407 $10,739 $5,189 $7,010 $10,071
Entergy New Orleans [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174
Entergy New Orleans [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $132 $50 $80 $21 $137 2017 $105 $48 $64 $18 $127
Entergy Texas [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projects benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,917 $14,933 $7,250 $10,883 $13,786 Pension contributions made through March 2018 $17,373 $19,510 $4,194 $2,061 $3,873 $3,715 Remaining estimated pension contributions to be made in 2018 $46,689 $52,407 $10,739 $5,189 $7,010 $10,071
Entergy Texas [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174
Entergy Texas [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the first quarters of 2018 and 2017: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2018 $132 $50 $80 $21 $137 2017 $105 $48 $64 $18 $127
System Energy [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $6,189 $8,446 $1,822 $673 $1,589 $1,776 Interest cost on projects benefit obligation 13,004 14,940 3,769 1,813 3,348 3,227 Expected return on assets (21,851 ) (24,809 ) (6,502 ) (2,993 ) (6,523 ) (4,991 ) Amortization of loss 13,412 14,450 3,610 1,954 2,626 3,715 Net pension cost $10,754 $13,027 $2,699 $1,447 $1,040 $3,727 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $5,090 $6,925 $1,472 $625 $1,364 $1,536 Interest cost on projected benefit obligation 12,944 14,809 3,732 1,791 3,392 3,091 Expected return on assets (20,427 ) (23,017 ) (6,131 ) (2,800 ) (6,180 ) (4,663 ) Amortization of loss 11,640 12,354 3,053 1,658 2,310 2,964 Net pension cost $9,247 $11,071 $2,126 $1,274 $886 $2,928
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018 : Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Expected 2018 pension contributions $64,062 $71,917 $14,933 $7,250 $10,883 $13,786 Pension contributions made through March 2018 $17,373 $19,510 $4,194 $2,061 $3,873 $3,715 Remaining estimated pension contributions to be made in 2018 $46,689 $52,407 $10,739 $5,189 $7,010 $10,071
System Energy [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the first quarters of 2018 and 2017, included the following components: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $793 $1,556 $321 $129 $330 $306 Interest cost on APBO 1,997 2,789 683 417 939 500 Expected return on assets (4,342 ) — (1,303 ) (1,313 ) (2,446 ) (783 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 289 388 377 34 206 233 Net other postretirement benefit cost ($2,541 ) $2,799 ($378 ) ($919 ) ($1,550 ) ($122 ) 2017 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Service cost - benefits earned during the period $863 $1,593 $290 $142 $372 $320 Interest cost on APBO 2,255 3,025 690 469 1,124 559 Expected return on assets (3,959 ) — (1,200 ) (1,159 ) (2,180 ) (717 ) Amortization of prior service credit (1,278 ) (1,934 ) (456 ) (186 ) (579 ) (378 ) Amortization of loss 1,115 465 419 105 826 390 Net other postretirement benefit cost ($1,004 ) $3,149 ($257 ) ($629 ) ($437 ) $174

Business Segment Information (T

Business Segment Information (Tables)	3 Months Ended
	Mar. 31, 2018
Segment Financial Information	Entergy’s segment financial information for the first quarters of 2018 and 2017 is as follows: Utility Entergy Wholesale Commodities All Other Eliminations Entergy (In Thousands) 2018 Operating revenues $2,304,990 $418,924 $— ($33 ) $2,723,881 Income taxes $52,224 ($1,078 ) ($7,483 ) $— $43,663 Consolidated net income (loss) $217,940 ($17,779 ) ($32,063 ) ($31,898 ) $136,200 Total assets as of March 31, 2018 $43,690,561 $5,504,233 $834,463 ($2,747,732 ) $47,281,525 2017 Operating revenues $2,035,112 $553,367 $— ($21 ) $2,588,458 Income taxes $98,492 ($78,337 ) ($12,392 ) $— $7,763 Consolidated net income (loss) $167,623 ($27,197 ) ($22,477 ) ($31,898 ) $86,051 Total assets as of December 31, 2017 $42,978,669 $5,638,009 $1,011,612 ($2,921,141 ) $46,707,149
Restructuring and Related Costs [Table Text Block]	Total restructuring charges for the first quarter 2018 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 January 1, 2018 $83 $14 $97 Restructuring costs accrued 26 — 26 Balance as of March 31, 2018 $109 $14 $123 Total restructuring charges for the first quarter 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 24 — 24 Balance as of March 31, 2017 $94 $21 $115

Risk Management And Fair Valu30

Risk Management And Fair Values (Tables)	3 Months Ended
	Mar. 31, 2018
Fair Values Of Derivative Instruments	The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of March 31, 2018 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $63 ($14) $49 Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $31 ($5) $26 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $13 ($13) $— Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $5 ($5) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $3 ($3) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $9 ($1) $8 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities $4 ($4) $— Entergy Wholesale Commodities Natural gas swaps Other current liabilities $1 $— $1 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2017 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Business (In Millions) Derivatives designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $19 ($19) $— Entergy Wholesale Commodities Electricity swaps and options Other deferred debits and other assets (non-current portion) $19 ($14) $5 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $86 ($20) $66 Entergy Wholesale Commodities Electricity swaps and options Other non-current liabilities (non-current portion) $17 ($14) $3 Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Electricity swaps and options Prepayments and other (current portion) $9 ($9) $— Entergy Wholesale Commodities Financial transmission rights Prepayments and other $22 ($1) $21 Utility and Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $9 ($8) $1 Entergy Wholesale Commodities Natural gas swaps Other current liabilities $6 $— $6 Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $1 million posted and $6 million held as of March 31, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes $69 million in letters of credit held as of March 31, 2018 and $34 million in letters of credit held as of December 31, 2017.
Derivative Instruments Designated As Cash Flow Hedges On Consolidated Statements Of Income	The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in other Income Statement location Amount of gain (loss) (In Millions) (In Millions) 2018 Electricity swaps and options $91 Competitive businesses operating revenues ($30) 2017 Electricity swaps and options $50 Competitive businesses operating revenues $51 (a) Before taxes of ($6) million and $18 million for the three months ended March 31, 2018 and 2017, respectively
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Amount of gain recognized in accumulated other comprehensive income Income Statement Amount of gain (loss) (In Millions) (In Millions) 2018 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights $— Purchased power expense (b) $32 Electricity swaps and options $— (c) Competitive business operating revenues $1 2017 Natural gas swaps $— Fuel, fuel-related expenses, and gas purchased for resale (a) ($7) Financial transmission rights $— Purchased power expense (b) $30 Electricity swaps and options $9 (c) Competitive business operating revenues $— (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items.
Assets and liabilities at fair value on a recurring basis	The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of March 31, 2018 and December 31, 2017 . The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,148 $— $— $1,148 Decommissioning trust funds (a): Equity securities 577 — — 577 Debt securities 1,084 1,535 — 2,619 Common trusts (b) 3,920 Power contracts — — 75 75 Securitization recovery trust account 52 — — 52 Escrow accounts 398 — — 398 Financial transmission rights — — 8 8 $3,259 $1,535 $83 $8,797 Liabilities: Gas hedge contracts $1 $— $— $1 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $725 $— $— $725 Decommissioning trust funds (a): Equity securities 526 — — 526 Debt securities 1,125 1,425 — 2,550 Common trusts (b) 4,136 Power contracts — — 5 5 Securitization recovery trust account 45 — — 45 Escrow accounts 406 — — 406 Financial transmission rights — — 21 21 $2,827 $1,425 $26 $8,414 Liabilities: Power contracts $— $— $70 $70 Gas hedge contracts 6 — — 6 $6 $— $70 $76 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2018 and 2017 : 2018 2017 Power Contracts Financial transmission rights Power Contracts Financial transmission rights (In Millions) Balance as of January 1, ($65 ) $21 $5 $21 Total gains (losses) for the period (a) Included in earnings 14 (1 ) — — Included in other comprehensive income 91 — 50 — Included as a regulatory liability/asset — 20 — 17 Settlements 35 (32 ) (50 ) (30 ) Balance as of March 31, $75 $8 $5 $8 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is $0.2 million for the three months ended March 31, 2018 and $0.4 million for the three months ended March 31, 2017.
Fair Value Inputs Liabilities Quantitative Information	The following table sets forth a description of the types of transactions classified as Level 3 in the fair value hierarchy and significant unobservable inputs to each which cause that classification as of March 31, 2018 : Transaction Type Fair Value as of March 31, 2018 Significant Unobservable Inputs Range from Average % Effect on Fair Value (In Millions) (In Millions) Power contracts - electricity swaps $75 Unit contingent discount +/- 4% - 4.75% $5 - $7
Entergy Arkansas [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of March 31, 2018 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $1.9 ($0.1 ) $1.8 Entergy Arkansas Financial transmission rights Prepayments and other $3.8 ($0.4 ) $3.4 Entergy Louisiana Financial transmission rights Prepayments and other $0.9 $— $0.9 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.4 $— $1.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Louisiana Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2 ) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8 ) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2 ) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of March 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas.
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.2) (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 $8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($3.5) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($6.1) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $4.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $15.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Assets and liabilities at fair value on a recurring basis	Entergy Arkansas 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Decommissioning trust funds (a): Equity securities $3.6 $— $— $3.6 Debt securities 111.3 239.5 — 350.8 Common trusts (b) 581.3 Securitization recovery trust account 7.9 — — 7.9 Financial transmission rights — — 1.8 1.8 $122.8 $239.5 $1.8 $945.4 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Decommissioning trust funds (a): Equity securities $11.7 $— $— $11.7 Debt securities 115.8 232.4 — 348.2 Common trusts (b) 585.0 Securitization recovery trust account 3.7 — — 3.7 Escrow accounts 2.4 — — 2.4 Financial transmission rights — — 3.0 3.0 $133.6 $232.4 $3.0 $954.0
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2018 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $3.0 $10.2 $2.1 $2.2 $3.4 Gains included as a regulatory liability/asset 6.8 10.8 6.6 1.8 (5.5 ) Settlements (8.0 ) (17.6 ) (7.8 ) (3.3 ) 3.5 Balance as of March 31, $1.8 $3.4 $0.9 $0.7 $1.4 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 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 Gains (losses) included as a regulatory liability/asset 0.1 10.8 1.2 1.8 3.2 Settlements (4.6 ) (15.2 ) (3.1 ) (2.4 ) (5.3 ) Balance as of March 31, $0.9 $4.1 $1.3 $0.5 $1.0
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 March 31, 2018 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $1.9 ($0.1 ) $1.8 Entergy Arkansas Financial transmission rights Prepayments and other $3.8 ($0.4 ) $3.4 Entergy Louisiana Financial transmission rights Prepayments and other $0.9 $— $0.9 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.4 $— $1.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Louisiana Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2 ) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8 ) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2 ) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of March 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas.
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.2) (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 $8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($3.5) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($6.1) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $4.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $15.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Assets and liabilities at fair value on a recurring basis	Entergy Louisiana 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $561.9 $— $— $561.9 Decommissioning trust funds (a): Equity securities 12.2 — — 12.2 Debt securities 145.6 370.7 — 516.3 Common trusts (b) 775.9 Escrow accounts 285.6 — — 285.6 Securitization recovery trust account 9.5 — — 9.5 Financial transmission rights — — 3.4 3.4 $1,014.8 $370.7 $3.4 $2,164.8 Liabilities: Gas hedge contracts $1.2 $— $— $1.2 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $30.1 $— $— $30.1 Decommissioning trust funds (a): Equity securities 15.2 — — 15.2 Debt securities 143.3 350.5 — 493.8 Common trusts (b) 803.1 Escrow accounts 289.5 — — 289.5 Securitization recovery trust account 2.0 — — 2.0 Financial transmission rights — — 10.2 10.2 $480.1 $350.5 $10.2 $1,643.9 Liabilities: Gas hedge contracts $5.0 $— $— $5.0
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2018 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $3.0 $10.2 $2.1 $2.2 $3.4 Gains included as a regulatory liability/asset 6.8 10.8 6.6 1.8 (5.5 ) Settlements (8.0 ) (17.6 ) (7.8 ) (3.3 ) 3.5 Balance as of March 31, $1.8 $3.4 $0.9 $0.7 $1.4 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 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 Gains (losses) included as a regulatory liability/asset 0.1 10.8 1.2 1.8 3.2 Settlements (4.6 ) (15.2 ) (3.1 ) (2.4 ) (5.3 ) Balance as of March 31, $0.9 $4.1 $1.3 $0.5 $1.0
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 March 31, 2018 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $1.9 ($0.1 ) $1.8 Entergy Arkansas Financial transmission rights Prepayments and other $3.8 ($0.4 ) $3.4 Entergy Louisiana Financial transmission rights Prepayments and other $0.9 $— $0.9 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.4 $— $1.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Louisiana Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2 ) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8 ) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2 ) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of March 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas.
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.2) (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 $8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($3.5) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($6.1) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $4.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $15.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Assets and liabilities at fair value on a recurring basis	Entergy Mississippi 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $0.3 $— $— $0.3 Escrow accounts 32.1 — — 32.1 Financial transmission rights — — 0.9 0.9 $32.4 $— $0.9 $33.3 Liabilities: Gas hedge contracts $0.2 $— $— $0.2 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $4.5 $— $— $4.5 Escrow accounts 32.0 — — 32.0 Financial transmission rights — — 2.1 2.1 $36.5 $— $2.1 $38.6 Liabilities: Gas hedge contracts $1.2 $— $— $1.2
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2018 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $3.0 $10.2 $2.1 $2.2 $3.4 Gains included as a regulatory liability/asset 6.8 10.8 6.6 1.8 (5.5 ) Settlements (8.0 ) (17.6 ) (7.8 ) (3.3 ) 3.5 Balance as of March 31, $1.8 $3.4 $0.9 $0.7 $1.4 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 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 Gains (losses) included as a regulatory liability/asset 0.1 10.8 1.2 1.8 3.2 Settlements (4.6 ) (15.2 ) (3.1 ) (2.4 ) (5.3 ) Balance as of March 31, $0.9 $4.1 $1.3 $0.5 $1.0
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 March 31, 2018 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $1.9 ($0.1 ) $1.8 Entergy Arkansas Financial transmission rights Prepayments and other $3.8 ($0.4 ) $3.4 Entergy Louisiana Financial transmission rights Prepayments and other $0.9 $— $0.9 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.4 $— $1.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Louisiana Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2 ) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8 ) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2 ) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of March 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas.
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.2) (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 $8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($3.5) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($6.1) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $4.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $15.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Assets and liabilities at fair value on a recurring basis	Entergy New Orleans 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1.3 $— $— $1.3 Securitization recovery trust account 4.8 — — 4.8 Escrow accounts 79.8 — — 79.8 Financial transmission rights — — 0.7 0.7 $85.9 $— $0.7 $86.6 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $32.7 $— $— $32.7 Securitization recovery trust account 1.5 — — 1.5 Escrow accounts 81.9 — — 81.9 Financial transmission rights — — 2.2 2.2 $116.1 $— $2.2 $118.3 Liabilities: Gas hedge contracts $0.2 $— $— $0.2
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2018 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $3.0 $10.2 $2.1 $2.2 $3.4 Gains included as a regulatory liability/asset 6.8 10.8 6.6 1.8 (5.5 ) Settlements (8.0 ) (17.6 ) (7.8 ) (3.3 ) 3.5 Balance as of March 31, $1.8 $3.4 $0.9 $0.7 $1.4 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 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 Gains (losses) included as a regulatory liability/asset 0.1 10.8 1.2 1.8 3.2 Settlements (4.6 ) (15.2 ) (3.1 ) (2.4 ) (5.3 ) Balance as of March 31, $0.9 $4.1 $1.3 $0.5 $1.0
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 March 31, 2018 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $1.9 ($0.1 ) $1.8 Entergy Arkansas Financial transmission rights Prepayments and other $3.8 ($0.4 ) $3.4 Entergy Louisiana Financial transmission rights Prepayments and other $0.9 $— $0.9 Entergy Mississippi Financial transmission rights Prepayments and other $0.7 $— $0.7 Entergy New Orleans Financial transmission rights Prepayments and other $1.4 $— $1.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Louisiana Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy Mississippi The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2017 are as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) Assets: Financial transmission rights Prepayments and other $3.2 ($0.2 ) $3.0 Entergy Arkansas Financial transmission rights Prepayments and other $11.0 ($0.8 ) $10.2 Entergy Louisiana Financial transmission rights Prepayments and other $2.1 $— $2.1 Entergy Mississippi Financial transmission rights Prepayments and other $2.2 $— $2.2 Entergy New Orleans Financial transmission rights Prepayments and other $3.6 ($0.2 ) $3.4 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Louisiana Natural gas swaps Other current liabilities $1.2 $— $1.2 Entergy Mississippi Natural gas swaps Other current liabilities $0.2 $— $0.2 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of March 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.2 million for Entergy Texas. As of December 31, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Arkansas, $0.1 million for Entergy Mississippi, and $0.05 million for Entergy Texas.
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended March 31, 2018 and 2017 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2018 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.2) (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 $8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $17.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.8 (b) Entergy Mississippi Financial transmission rights Purchased power expense $3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense ($3.5) (b) Entergy Texas 2017 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($6.1) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $4.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $15.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Assets and liabilities at fair value on a recurring basis	Entergy Texas 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $39.0 $— $— $39.0 Securitization recovery trust account 29.7 — — 29.7 Financial transmission rights — — 1.4 1.4 $68.7 $— $1.4 $70.1 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $115.5 $— $— $115.5 Securitization recovery trust account 37.7 — — 37.7 Financial transmission rights — — 3.4 3.4 $153.2 $— $3.4 $156.6
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2018 . Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, $3.0 $10.2 $2.1 $2.2 $3.4 Gains included as a regulatory liability/asset 6.8 10.8 6.6 1.8 (5.5 ) Settlements (8.0 ) (17.6 ) (7.8 ) (3.3 ) 3.5 Balance as of March 31, $1.8 $3.4 $0.9 $0.7 $1.4 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended March 31, 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 Gains (losses) included as a regulatory liability/asset 0.1 10.8 1.2 1.8 3.2 Settlements (4.6 ) (15.2 ) (3.1 ) (2.4 ) (5.3 ) Balance as of March 31, $0.9 $4.1 $1.3 $0.5 $1.0
System Energy [Member]
Assets and liabilities at fair value on a recurring basis	System Energy 2018 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $278.7 $— $— $278.7 Decommissioning trust funds (a): Equity securities 2.3 — — 2.3 Debt securities 172.5 153.1 — 325.6 Common trusts (b) 568.3 $453.5 $153.1 $— $1,174.9 2017 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $287.1 $— $— $287.1 Decommissioning trust funds (a): Equity securities 3.1 — — 3.1 Debt securities 187.2 143.3 — 330.5 Common trusts (b) 572.1 $477.4 $143.3 $— $1,192.8

Decommissioning Trust Funds (Ta

Decommissioning Trust Funds (Tables)	3 Months Ended
	Mar. 31, 2018
Securities Held	The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 2,619 23 48 2017 Equity Securities $4,662 $2,131 $1 Debt Securities 2,550 44 16 Total $7,212 $2,175 $17
Available For Sale Securities Continuous Unrealized Loss Position Fair Value	The fair value and gross unrealized losses of the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $1,667 $35 More than 12 months 241 13 Total $1,908 $48 The fair value and gross unrealized losses of available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $8 $1 $1,099 $7 More than 12 months — — 265 9 Total $8 $1 $1,364 $16
Fair Value Of Debt Securities By Contractual Maturities	The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $89 $74 1 year - 5 years 928 902 5 years - 10 years 784 812 10 years - 15 years 152 147 15 years - 20 years 101 100 20 years+ 565 515 Total $2,619 $2,550
Entergy Arkansas [Member]
Securities Held	Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 350.8 0.5 9.7 2017 Equity Securities $596.7 $354.9 $— Debt Securities 348.2 2.1 3.0 Total $944.9 $357.0 $3.0
Available For Sale Securities Continuous Unrealized Loss Position Fair Value	The fair value and gross unrealized losses of the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $277.8 $7.2 More than 12 months 42.5 2.5 Total $320.3 $9.7 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $168.0 $1.2 More than 12 months — — 41.4 1.8 Total $— $— $209.4 $3.0
Fair Value Of Debt Securities By Contractual Maturities	The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $14.1 $13.0 1 year - 5 years 130.6 123.4 5 years - 10 years 177.9 180.6 10 years - 15 years 3.4 4.8 15 years - 20 years 7.0 3.4 20 years+ 17.8 23.0 Total $350.8 $348.2
Entergy Louisiana [Member]
Securities Held	Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 516.3 5.7 8.4 2017 Equity Securities $818.3 $461.2 $— Debt Securities 493.8 10.9 3.6 Total $1,312.1 $472.1 $3.6
Available For Sale Securities Continuous Unrealized Loss Position Fair Value	The fair value and gross unrealized losses of the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $254.9 $4.6 More than 12 months 78.8 3.8 Total $333.7 $8.4 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $135.3 $1.1 More than 12 months — — 84.4 2.5 Total $— $— $219.7 $3.6
Fair Value Of Debt Securities By Contractual Maturities	The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $28.1 $23.2 1 year - 5 years 136.7 122.8 5 years - 10 years 108.4 109.3 10 years - 15 years 52.9 52.7 15 years - 20 years 44.7 50.7 20 years+ 145.5 135.1 Total $516.3 $493.8
System Energy [Member]
Securities Held	System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of March 31, 2018 and December 31, 2017 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2018 Debt Securities 325.6 1.4 5.8 2017 Equity Securities $575.2 $308.6 $— Debt Securities 330.5 4.2 1.2 Total $905.7 $312.8 $1.2
Available For Sale Securities Continuous Unrealized Loss Position Fair Value	The fair value and gross unrealized losses of the available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of March 31, 2018 : Debt Securities Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $240.7 $5.5 More than 12 months 10.2 0.3 Total $250.9 $5.8 The fair value and gross unrealized losses of the available-for-sale securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2017 : Equity Securities Debt Securities Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $— $— $196.9 $1.0 More than 12 months — — 10.4 0.2 Total $— $— $207.3 $1.2
Fair Value Of Debt Securities By Contractual Maturities	The fair value of debt securities, summarized by contractual maturities, as of March 31, 2018 and December 31, 2017 are as follows: 2018 2017 (In Millions) less than 1 year $5.5 $4.1 1 year - 5 years 164.5 173.0 5 years - 10 years 78.4 78.5 10 years - 15 years 3.8 1.0 15 years - 20 years 10.7 6.9 20 years+ 62.7 67.0 Total $325.6 $330.5

Revenue Recognition Revenue Rec

Revenue Recognition Revenue Recognition (Tables)	3 Months Ended
	Mar. 31, 2018
Disaggregation of Revenue [Table Text Block]	Entergy’s total revenues for the three months ended March 31, 2018 were as follows: 2018 (In Thousands) Utility: Residential $892,085 Commercial 595,720 Industrial 597,186 Governmental 56,478 Total billed retail 2,141,469 Sales for resale (a) 69,526 Other electric revenues (b) 27,433 Non-customer revenues (c) 9,834 Total electric revenues 2,248,262 Natural gas 56,695 Entergy Wholesale Commodities: Competitive businesses sales (a) 409,135 Non-customer revenues (c) 9,789 Total competitive businesses 418,924 Total operating revenues $2,723,881
Entergy Arkansas [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $235,524 $295,517 $148,342 $64,575 $148,126 Commercial 120,634 224,928 110,460 54,272 85,427 Industrial 111,477 352,336 42,501 7,570 83,302 Governmental 4,648 17,310 10,848 17,691 5,981 Total billed retail 472,283 890,091 312,151 144,108 322,836 Sales for resale (a) 66,103 89,255 1,993 13,337 23,361 Other electric revenues (b) 10,024 20,503 (719 ) (3,111 ) 2,264 Non-customer revenues (c) 2,614 5,257 2,318 1,484 479 Total electric revenues 551,024 1,005,106 315,743 155,818 348,940 Natural gas — 24,238 — 32,457 — Total operating revenues $551,024 $1,029,344 $315,743 $188,275 $348,940
Entergy Louisiana [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $235,524 $295,517 $148,342 $64,575 $148,126 Commercial 120,634 224,928 110,460 54,272 85,427 Industrial 111,477 352,336 42,501 7,570 83,302 Governmental 4,648 17,310 10,848 17,691 5,981 Total billed retail 472,283 890,091 312,151 144,108 322,836 Sales for resale (a) 66,103 89,255 1,993 13,337 23,361 Other electric revenues (b) 10,024 20,503 (719 ) (3,111 ) 2,264 Non-customer revenues (c) 2,614 5,257 2,318 1,484 479 Total electric revenues 551,024 1,005,106 315,743 155,818 348,940 Natural gas — 24,238 — 32,457 — Total operating revenues $551,024 $1,029,344 $315,743 $188,275 $348,940
Entergy Mississippi [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $235,524 $295,517 $148,342 $64,575 $148,126 Commercial 120,634 224,928 110,460 54,272 85,427 Industrial 111,477 352,336 42,501 7,570 83,302 Governmental 4,648 17,310 10,848 17,691 5,981 Total billed retail 472,283 890,091 312,151 144,108 322,836 Sales for resale (a) 66,103 89,255 1,993 13,337 23,361 Other electric revenues (b) 10,024 20,503 (719 ) (3,111 ) 2,264 Non-customer revenues (c) 2,614 5,257 2,318 1,484 479 Total electric revenues 551,024 1,005,106 315,743 155,818 348,940 Natural gas — 24,238 — 32,457 — Total operating revenues $551,024 $1,029,344 $315,743 $188,275 $348,940
Entergy New Orleans [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $235,524 $295,517 $148,342 $64,575 $148,126 Commercial 120,634 224,928 110,460 54,272 85,427 Industrial 111,477 352,336 42,501 7,570 83,302 Governmental 4,648 17,310 10,848 17,691 5,981 Total billed retail 472,283 890,091 312,151 144,108 322,836 Sales for resale (a) 66,103 89,255 1,993 13,337 23,361 Other electric revenues (b) 10,024 20,503 (719 ) (3,111 ) 2,264 Non-customer revenues (c) 2,614 5,257 2,318 1,484 479 Total electric revenues 551,024 1,005,106 315,743 155,818 348,940 Natural gas — 24,238 — 32,457 — Total operating revenues $551,024 $1,029,344 $315,743 $188,275 $348,940
Entergy Texas [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended March 31, 2018 were as follows: 2018 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Residential $235,524 $295,517 $148,342 $64,575 $148,126 Commercial 120,634 224,928 110,460 54,272 85,427 Industrial 111,477 352,336 42,501 7,570 83,302 Governmental 4,648 17,310 10,848 17,691 5,981 Total billed retail 472,283 890,091 312,151 144,108 322,836 Sales for resale (a) 66,103 89,255 1,993 13,337 23,361 Other electric revenues (b) 10,024 20,503 (719 ) (3,111 ) 2,264 Non-customer revenues (c) 2,614 5,257 2,318 1,484 479 Total electric revenues 551,024 1,005,106 315,743 155,818 348,940 Natural gas — 24,238 — 32,457 — Total operating revenues $551,024 $1,029,344 $315,743 $188,275 $348,940

Rate And Regulatory Matters (Na

Rate And Regulatory Matters (Narrative) (Details)	1 Months Ended						3 Months Ended
	Apr. 30, 2018USD ($)	Mar. 31, 2018USD ($)$ / kWh	Jan. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Aug. 31, 2017	Jul. 31, 2015USD ($)	Mar. 31, 2018USD ($)	Mar. 31, 2017USD ($)
Regulatory Assets [Line Items]
Impairment of Long-Lived Assets Held-for-use							$ 25,800,000	$ 145,026,000
Deferred Fuel Cost		$ 83,445,000		$ 95,746,000			83,445,000
Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Earned return on common equity			9.06%
Authorized return on common equity					9.95%
Earnings bandwidth basis points					16000.00%
Reduced earnings bandwidth basis points					8000.00%
Public Utilities, Requested Increase in Revenue Requirement			$ 100,000
Monthly increase in regulatory liability related to Tax Act			$ 9,100,000
Regulatory liability related to Tax Act		27,000,000					27,000,000
Entergy Louisiana [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Earned return on common equity	10.79%
Public Utilities, proposed customer credits	$ 700,000
Proposed prospective reduction in the gas infrastructure rider	$ 200,000
Authorized return on common equity	9.95%
Target earned return on common equity	9.80%
Common equity basis point bandwidth	$ 60
Cap on potential revenue increase for 2018 rate case evaluation period	35,000,000
Cap on potential revenue increase for 2018 and 2019 rate case evaluation periods	70,000,000
Requirement for excess transmission project costs eligible for costs recovery mechanism	$ 100,000,000
Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Deferred Fuel Cost		18,627,000		32,444,000			18,627,000
Proposed customer credits due to internal restructuring		27,000,000
Preferred Stock, Redemption Amount		21,200,000
Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Deferred Fuel Cost		3,535,000		0			3,535,000
Benefit to electric customers related to reduction in income tax expense under Tax Act		8,200,000
Benefit to gas customers related to reduction in income tax expense under Tax Act		1,300,000
Entergy Texas [Member]
Regulatory Assets [Line Items]
System Agreement Bandwidth Remedy Payments						$ 10,900,000
Refund for fuel cost recovery				30,500,000
Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Deferred Fuel Cost		$ 61,282,000		$ 63,302,000			$ 61,282,000
Rate At Which Electricity Sold To Retail Customers | $ / kWh		0.01547
Increase in Rate At Which Electricity Sold To Retail Customers | $ / kWh		0.01882

Rate And Regulatory Matters R34

Rate And Regulatory Matters Rate and Regulatory Matters (Payments/Receipts Among The Utility Operating Companies) (Details) $ in Millions	Mar. 31, 2018USD ($)
Entergy Arkansas [Member]
Payments (receipts) based on production costs	$ 6
Entergy New Orleans [Member]
Payments (receipts) based on production costs	2
Entergy Texas [Member]
Payments (receipts) based on production costs	$ (8)

Equity (Narrative) (Details)

Equity (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands		Apr. 11, 2018	Mar. 31, 2018	Mar. 31, 2017	Jan. 01, 2018
Equity [Abstract]
Stock Options Excluded From Diluted Common Shares Outstanding Calculation			4,000,000	4,900,000
Shares, Issued			281,614
Common stock dividend (in dollars per share)			$ 0.89	$ 0.87
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax					$ 632,617
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	[1]				$ 56,360
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects			$ 15,505
Tax Cuts and Jobs Act, Portion Reclassified from AOCI to Retained Earnings			32,000
Tax Cuts and Jobs Act, Portion Reclassified from AOCI to Regulatory Liability for Income Taxes			$ 16,500
Subsequent Event [Member]
Equity [Abstract]
Common stock dividend (in dollars per share)		$ 0.89
[1]	Text selection found with no content.

Equity (Schedule Of Earnings Pe

Equity (Schedule Of Earnings Per Share, Basic And Diluted) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Incremental Weighted Average Shares Attributable to Dilutive Effect [Abstract]
Stock options, Shares	200,000	100,000
Stock options $/share	$ 0	$ 0
Restricted stock, Shares	500,000	400,000
Restricted stock $/share	$ 0	$ 0
Basic earnings per share
Net income (loss) attributable to Entergy Corporation, Income	$ 132,761	$ 82,605
Net Income Attributable to Entergy Corporation, Shares	180,707,575	179,335,063
Net Income Attributable to Entergy Corporation, $/share	$ 0.7346731314	$ 0.46
Diluted earnings per share, Shares	181,431,968	179,842,053
Diluted earnings per share $/share	$ 0.73	$ 0.46

Equity (Accumulated Other Compr

Equity (Accumulated Other Comprehensive Income (Loss))(Details) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2018	Mar. 31, 2017	Jan. 01, 2018	Dec. 31, 2017	Dec. 31, 2016
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax				$ (632,617)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss		$ (561,498)	$ 10,960		$ (23,531)	$ (34,971)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax		72,404	72,480
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		6,741	(26,549)
Other comprehensive income (loss)		79,145	45,931
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect	[1]	(16,538)
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects		15,505
Restatement Adjustment [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss				(656,148)
Accumulated Foreign Currency Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss			748			748
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax			0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax			0
Other comprehensive income (loss)			0
Accumulated Net Investment Gain (Loss) Attributable to Parent [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax				(632,617)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss		(6,201)	467,561		545,045	429,734
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax		838	39,872
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		(33,694)	(2,045)
Other comprehensive income (loss)		(32,856)	37,827
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects		114,227
Accumulated Net Investment Gain (Loss) Attributable to Parent [Member] | Restatement Adjustment [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss				(87,572)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax				0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss		(605,491)	(460,814)		(531,099)	(469,446)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax		0	0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		16,574	8,632
Other comprehensive income (loss)		16,574	8,632
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects		(90,966)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Restatement Adjustment [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss				(531,099)
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax				0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss		50,194	3,465		(37,477)	3,993
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax		71,566	32,608
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		23,861	(33,136)
Other comprehensive income (loss)		95,427	(528)
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects		(7,756)
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | Restatement Adjustment [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss				$ (37,477)
Entergy Louisiana [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss		(56,950)			(46,400)
Other comprehensive income (loss)		(501)	(370)
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect		(3,787)
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss		(56,950)	(48,812)		$ (46,400)	$ (48,442)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		(501)	(370)
Other comprehensive income (loss)		(501)	(370)
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect		$ (10,049)	$ 0
[1]	Text selection found with no content.

Equity (Reclassification out of

Equity (Reclassification out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2018	Mar. 31, 2017
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Competitive Energy Revenue		$ 418,924	$ 553,367
Other Nonoperating Income (Expense)		(31,356)	(15,189)
INCOME BEFORE INCOME TAXES		179,863	93,814
Income taxes (benefits)		(43,663)	(7,763)
Consolidated net income	[1]	136,200	86,051
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Consolidated net income		(6,741)	26,549
Accumulated Net Investment Gain (Loss) Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Consolidated net income		33,694	2,045
Parent Company [Member] | Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Competitive Energy Revenue		(30,082)	51,227
Other Nonoperating Income (Expense)		(122)	(250)
INCOME BEFORE INCOME TAXES		(30,204)	50,977
Income taxes (benefits)		6,343	(17,841)
Consolidated net income		(23,861)	33,136
Parent Company [Member] | Accumulated Net Investment Gain (Loss) Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Realized gain (loss)		53,314	4,010
Income taxes (benefits)		(19,620)	(1,965)
Parent Company [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior-service credit		5,426	6,562
Amortization of loss		(24,952)	(21,571)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement		(1,616)	0
INCOME BEFORE INCOME TAXES		(21,142)	(15,009)
Income taxes (benefits)		4,568	6,377
Consolidated net income		(16,574)	(8,632)
Entergy Louisiana [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Nonoperating Income (Expense)		(7,665)	(9,142)
INCOME BEFORE INCOME TAXES		133,341	137,303
Income taxes (benefits)		(21,748)	(42,925)
Consolidated net income		111,593	94,378
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior-service credit		1,934	1,934
Amortization of loss		(1,257)	(1,332)
INCOME BEFORE INCOME TAXES		677	602
Income taxes (benefits)		(176)	(232)
Consolidated net income		$ 501	$ 370
[1]	Text selection found with no content.

Revolving Credit Facilities, 39

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended		3 Months Ended
	May 31, 2018	Mar. 31, 2018	Mar. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Amount of Facility		$ 3,500,000	$ 3,500,000
Amount of total borrowing capacity against which fronting commitments exist		20,000	20,000
Letters of Credit Outstanding, Amount		69,000	$ 69,000	$ 34,000
Line of credit facility, commitment fee percentage			0.225%
Amount Drawn/ Outstanding		1,125,000	$ 1,125,000
Commercial Paper program limit		2,000,000	2,000,000
Commercial Paper Amount Outstanding		$ 655,000	$ 655,000
Commercial Paper Program [Member]
Debt Instrument [Line Items]
Debt, weighted average interest rate		1.88%	1.88%
Credit Facility [Member]
Debt Instrument [Line Items]
Debt, weighted average interest rate		3.31%	3.31%
Entergy Arkansas [Member]
Debt Instrument [Line Items]
Short-term borrowings		$ 43,887	$ 43,887	49,974
Authorized Short Term Borrowings		250,000	250,000
Amount of total borrowing capacity against which fronting commitments exist		5,000	5,000
Letters of Credit Outstanding, Amount		200	200	200
Entergy Louisiana [Member]
Debt Instrument [Line Items]
Short-term borrowings		62,922	62,922	43,540
Authorized Short Term Borrowings		450,000	450,000
Amount of total borrowing capacity against which fronting commitments exist		15,000	$ 15,000
Entergy Louisiana [Member] | Mortgage Bonds, Four Point Zero Zero Percent due March Twenty Thirty Three [Member]
Debt Instrument [Line Items]
Issuance Of Debt		$ 750,000
Debt instrument, interest rate, stated percentage		4.00%	4.00%
Entergy Mississippi [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		$ 175,000	$ 175,000
Letters of Credit Outstanding, Amount		100	100	100
Entergy Texas [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		200,000	200,000
Amount of total borrowing capacity against which fronting commitments exist		30,000	30,000
Letters of Credit Outstanding, Amount		200	200	50
System Energy [Member]
Debt Instrument [Line Items]
Short-term borrowings		43,170	43,170	$ 17,830
Authorized Short Term Borrowings		200,000	200,000
Entergy Nuclear Vermont Yankee [Member]
Debt Instrument [Line Items]
Amount of Facility		145,000	$ 145,000
Line of credit facility, commitment fee percentage			0.20%
Amount Drawn/ Outstanding		118,000	$ 118,000
Line of Credit Facility, Interest Rate During Period			3.10%
Entergy New Orleans [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings		150,000	$ 150,000
Amount of total borrowing capacity against which fronting commitments exist		10,000	10,000
System Energy VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		$ 43,200	$ 43,200
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%	3.78%
System Energy VIE [Member] | Three Point Four Two Percent Series J Notes Due April Two Thousand Twenty One [Member]
Debt Instrument [Line Items]
Issuance Of Debt		$ 100,000
Debt instrument, interest rate, stated percentage		3.42%	3.42%
Entergy Arkansas VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		$ 43,900	$ 43,900
Line of credit facility commitment fee as a percentage of undrawn commitment amount			0.10%
Entergy Arkansas VIE [Member] | Three Point Six Five Percent Series L Notes Due July Two Thousand Twenty One [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		3.65%	3.65%
Entergy Louisiana Waterford VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		$ 62,900	$ 62,900
Line of credit facility commitment fee as a percentage of undrawn commitment amount			0.10%
Entergy Louisiana Waterford VIE [Member] | Three Point Nine Two Percent Series H Dues February Two Thousand Twenty One [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		3.92%	3.92%
Entergy Louisiana River Bend VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding		$ 52,300	$ 52,300
Line of credit facility commitment fee as a percentage of undrawn commitment amount			0.10%
Maximum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment fee percentage			0.275%
Consolidated debt ratio		0.65	0.65
Maximum [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65	0.65
Consolidated debt ratio of total capitalization			70.00%
Maximum [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65	0.65
Consolidated debt ratio of total capitalization			70.00%
Maximum [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65	0.65
Maximum [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65	0.65
Maximum [Member] | System Energy [Member]
Debt Instrument [Line Items]
Consolidated debt ratio of total capitalization			70.00%
Maximum [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Consolidated debt ratio		0.65	0.65
Minimum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment fee percentage			0.075%
Credit Facility Of Three Hundred Fifty Million [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Amount of Facility		$ 350,000	$ 350,000
Letters of Credit Outstanding, Amount		9,100	9,100
Amount Drawn/ Outstanding		100,000	$ 100,000
Line of Credit Facility, Interest Rate During Period			2.94%
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Amount of Facility		150,000	$ 150,000
Letters of Credit Outstanding, Amount		0	0
Amount Drawn/ Outstanding		50,000	$ 50,000
Line of Credit Facility, Interest Rate During Period			3.12%
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Amount of Facility		150,000	$ 150,000
Letters of Credit Outstanding, Amount		24,400	24,400
Amount Drawn/ Outstanding		$ 0	$ 0
Line of Credit Facility, Interest Rate During Period			3.39%
Subsequent Event [Member] | Entergy Louisiana [Member] | Mortgage Bonds Six Point Zero Percent Series Due May Twenty Eighteen [Member]
Debt Instrument [Line Items]
Redemption of debt instrument	$ 375,000
Debt instrument, interest rate, stated percentage	6.00%

Revolving Credit Facilities, 40

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Summary Of The Borrowings Outstanding And Capacity Available Under The Facility) (Details) $ in Millions	Mar. 31, 2018USD ($)
Summary of the borrowings outstanding and capacity available under the facility
Capacity	$ 3,500
Amount Drawn/ Outstanding	1,125
Letters of Credit	6
Capacity Available	$ 2,369

Revolving Credit Facilities, 41

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Credit Facilities) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Dec. 31, 2017
Amount of total borrowing capacity against which fronting commitments exist	$ 20,000
Amount of Facility	3,500,000
Amount Drawn/ Outstanding	1,125,000
Letters of Credit Outstanding, Amount	69,000	$ 34,000
Entergy Arkansas [Member]
Amount of total borrowing capacity against which fronting commitments exist	5,000
Letters of Credit Outstanding, Amount	$ 200	200
Entergy Arkansas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Aug. 14, 2022
Amount of Facility	$ 150,000
Interest Rate	3.12%
Amount Drawn/ Outstanding	$ 50,000
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	3.14%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Louisiana [Member]
Amount of total borrowing capacity against which fronting commitments exist	$ 15,000
Entergy Louisiana [Member] | Credit Facility Of Three Hundred Fifty Million [Member]
Expiration Date	Aug. 14, 2022
Amount of Facility	$ 350,000
Interest Rate	2.94%
Amount Drawn/ Outstanding	$ 100,000
Letters of Credit Outstanding, Amount	9,100
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	3.39%
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	3.39%
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	3.39%
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	3.39%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy New Orleans [Member]
Amount of total borrowing capacity against which fronting commitments exist	$ 10,000
Entergy New Orleans [Member] | Credit Facility Of Twenty Five Million [Member]
Expiration Date	Nov. 20, 2018
Amount of Facility	$ 25,000
Interest Rate	3.36%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	800
Entergy Texas [Member]
Amount of total borrowing capacity against which fronting commitments exist	30,000
Letters of Credit Outstanding, Amount	$ 200	$ 50
Entergy Texas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Aug. 14, 2022
Amount of Facility	$ 150,000
Interest Rate	3.39%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 24,400

Revolving Credit Facilities, 42

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Short-Term Borrowings And The Outstanding Short-Term Borrowings) (Details) $ in Millions	Mar. 31, 2018USD ($)
Entergy Arkansas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	$ 250
Borrowings	124
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	75
Entergy New Orleans [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	150
Borrowings	0
Entergy Texas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	0
System Energy [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	$ 0

Revolving Credit Facilities, 43

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2018USD ($)
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount Drawn/ Outstanding	$ 1,125
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	3.74%
Amount Drawn/ Outstanding	$ 43.9
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	3.46%
Amount Drawn/ Outstanding	$ 43.2
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	2.82%
Amount Drawn/ Outstanding	$ 52.3
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	3.35%
Amount Drawn/ Outstanding	$ 62.9
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%

Revolving Credit Facilities, 44

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Notes Payable By Variable Interest Entities) (Details) $ in Millions	Mar. 31, 2018USD ($)
Three Point Six Five Percent Series L Notes Due July Two Thousand Twenty One [Member] | Entergy Arkansas VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.65%
Amount	$ 90
Three Point One Seven Percent Series M Notes Due December Two Thousand Twenty Three [Member] | Entergy Arkansas VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.17%
Amount	$ 40
Three Point Three Eight Percent Series R Notes Due August Two Thousand Twenty [Member] | Entergy Louisiana River Bend VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.38%
Amount	$ 70
Three Point Nine Two Percent Series H Dues February Two Thousand Twenty One [Member] | Entergy Louisiana Waterford VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.92%
Amount	$ 40
Three Point Two Two Percent Series I Notes Due December Two Thousand Twenty Three [Domain] | Entergy Louisiana Waterford VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.22%
Amount	$ 20
Three Point Seven Eight Percent Series I Notes Due October Two Thousand Eighteen [Member] | System Energy VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.78%
Amount	$ 85
Three Point Four Two Percent Series J Notes Due April Two Thousand Twenty One [Member] | System Energy VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.42%
Amount	$ 100

Revolving Credit Facilities, 45

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Book Value And The Fair Value Of Long-Term Debt) (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Long-term Debt, Fair Value	$ 16,771,585	$ 15,367,453
Long-term Debt, Book Value	16,851,636	15,075,266
Entergy Arkansas [Member]
Long-term Debt, Fair Value	2,812,019	2,865,844
Long-term Debt, Book Value	2,978,569	2,952,399
Long term DOE obligations	184,000	183,000
Entergy Louisiana [Member]
Long-term Debt, Fair Value	7,022,323	6,389,774
Long-term Debt, Book Value	6,938,439	6,144,071
Entergy Mississippi [Member]
Long-term Debt, Fair Value	1,252,877	1,285,741
Long-term Debt, Book Value	1,270,399	1,270,122
Entergy New Orleans [Member]
Long-term Debt, Fair Value	446,981	455,968
Long-term Debt, Book Value	436,995	436,870
Entergy Texas [Member]
Long-term Debt, Fair Value	1,603,892	1,661,902
Long-term Debt, Book Value	1,562,555	1,587,150
System Energy [Member]
Long-term Debt, Fair Value	576,121	529,119
Long-term Debt, Book Value	601,582	551,488
Capital Lease Obligations	$ 34,000	$ 34,000

Revolving Credit Facilities, 46

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations) (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Letters of Credit Outstanding, Amount	$ 69,000	$ 34,000
Entergy Arkansas [Member]
Letters of Credit Outstanding, Amount	200	200
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	100	100
Entergy Texas [Member]
Letters of Credit Outstanding, Amount	200	$ 50
Credit Facility Of Twenty Five Million [Member] | Entergy Arkansas [Member]
Uncommitted Credit Facility	$ 25,000
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 1,000
Credit Facility of Fifty Million [Member] | Entergy Texas [Member]
Uncommitted Credit Facility	$ 50,000
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 25,600
Credit Facility of Forty Million [Member] | Entergy Mississippi [Member]
Uncommitted Credit Facility	$ 40,000
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 16,600
Credit Facility of Fifteen Million [Member] | Entergy New Orleans [Member]
Uncommitted Credit Facility	$ 15,000
Letter of Credit Fee, Percentage	1.00%
Letters of Credit Outstanding, Amount	$ 4,800
Credit Facility Of One Hundred Twenty Five Million [Member] | Entergy Louisiana [Member]
Uncommitted Credit Facility	$ 125,000
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 23,800

Stock Based Compensation (Narra

Stock Based Compensation (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	Jan. 25, 2018	Mar. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option granted (in shares)	687,400
Weighted-average grant-date fair value of options granted (in dollars per share)	$ 6.99
Stock options outstanding		4,393,990
Weighted-average exercise price of stock options outstanding (in dollars per share)		$ 74.39
Intrinsic value in the money stock options		$ 19.3
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]
Restricted stock awards granted value (in dollars per share)	78.08
LTIP awards granted value (in dollars per share)	86.75
LTIP awards granted value based on stock price (in dollars per share)	$ 78.08
Restricted Awards [Member] | Equity Ownership And Long Term Cash Incentive Plan Two Thousand Fifteen [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock awards granted	333,850
Long Term Incentive Plan [Member] | Equity Ownership And Long Term Cash Incentive Plan Two Thousand Fifteen [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Long-term incentive plan awards	182,408

Stock-Based Compensation (Finan

Stock-Based Compensation (Financial Information For Stock Options) (Details) - Employee Stock Option [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 1.1	$ 1.1
Tax benefit recognized in Entergy's net income	0.3	0.4
Compensation cost capitalized as part of fixed assets and inventory	$ 0.2	$ 0.2

Stock-Based Compensation (Fin49

Stock-Based Compensation (Financial Information For Other Equity Plans) (Details) - Restricted Stock Awards [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 8.8	$ 8.2
Tax benefit recognized in Entergy's net income	2.2	3.1
Compensation cost capitalized as part of fixed assets and inventory	$ 2.3	$ 2

Retirement And Other Postreti50

Retirement And Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Change on Operating Results		$ 21,000	$ 108,000	$ 71,000	$ 148,000
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	$ 91,800
Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Change on Operating Results		2,800	13,700	13,400	30,700
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	17,373
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Change on Operating Results		6,100	27,800	26,100	50,700
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	19,510
Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Change on Operating Results		600	2,700	2,400	6,300
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	4,194
Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Change on Operating Results		200	1,300	1,000	4,000
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	2,061
Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Change on Operating Results		(200)	200	(1,100)	4,000
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	3,873
System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Change on Operating Results		900	$ 6,200	$ 5,100	$ 10,200
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	3,715
Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year						$ 352,100
Subsequent Event [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year						64,062
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year						46,689
Subsequent Event [Member] | Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year						71,917
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year						52,407
Subsequent Event [Member] | Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year						14,933
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year						10,739
Subsequent Event [Member] | Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year						7,250
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year						5,189
Subsequent Event [Member] | Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year						10,883
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year						7,010
Subsequent Event [Member] | System Energy [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year						13,786
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year						$ 10,071
Non Qualified Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	8,900	4,600
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits	4,400
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	132	105
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits	12
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	50	48
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	80	64
Non Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	21	18
Non Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs	$ 137	$ 127

Retirement And Other Postreti51

Retirement And Other Postretirement Benefits (Components Of Qualified Net Pension Cost) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	$ 38,752	$ 33,410
Interest cost on projected benefit obligation	66,854	65,206
Expected return on assets	(110,535)	(102,056)
Amortization of prior service cost (credit)	99	65
Amortization of loss	68,526	56,930
Net other postretirement benefit cost	63,696	53,555
Pension Plans Defined Benefit [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	6,189	5,090
Interest cost on projected benefit obligation	13,004	12,944
Expected return on assets	(21,851)	(20,427)
Amortization of loss	13,412	11,640
Net other postretirement benefit cost	10,754	9,247
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	8,446	6,925
Interest cost on projected benefit obligation	14,940	14,809
Expected return on assets	(24,809)	(23,017)
Amortization of loss	14,450	12,354
Net other postretirement benefit cost	13,027	11,071
Pension Plans Defined Benefit [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,822	1,472
Interest cost on projected benefit obligation	3,769	3,732
Expected return on assets	(6,502)	(6,131)
Amortization of loss	3,610	3,053
Net other postretirement benefit cost	2,699	2,126
Pension Plans Defined Benefit [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	673	625
Interest cost on projected benefit obligation	1,813	1,791
Expected return on assets	(2,993)	(2,800)
Amortization of loss	1,954	1,658
Net other postretirement benefit cost	1,447	1,274
Pension Plans Defined Benefit [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,589	1,364
Interest cost on projected benefit obligation	3,348	3,392
Expected return on assets	(6,523)	(6,180)
Amortization of loss	2,626	2,310
Net other postretirement benefit cost	1,040	886
Pension Plans Defined Benefit [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,776	1,536
Interest cost on projected benefit obligation	3,227	3,091
Expected return on assets	(4,991)	(4,663)
Amortization of loss	3,715	2,964
Net other postretirement benefit cost	3,727	2,928
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	6,782	6,729
Interest cost on projected benefit obligation	12,681	13,960
Expected return on assets	(10,373)	(9,408)
Amortization of prior service cost (credit)	(9,251)	(10,356)
Amortization of loss	3,432	5,476
Net other postretirement benefit cost	3,271	6,401
Other Postretirement [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	793	863
Interest cost on projected benefit obligation	1,997	2,255
Expected return on assets	(4,342)	(3,959)
Amortization of prior service cost (credit)	(1,278)	(1,278)
Amortization of loss	289	1,115
Net other postretirement benefit cost	(2,541)	(1,004)
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,556	1,593
Interest cost on projected benefit obligation	2,789	3,025
Expected return on assets	0	0
Amortization of prior service cost (credit)	(1,934)	(1,934)
Amortization of loss	388	465
Net other postretirement benefit cost	2,799	3,149
Other Postretirement [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	321	290
Interest cost on projected benefit obligation	683	690
Expected return on assets	(1,303)	(1,200)
Amortization of prior service cost (credit)	(456)	(456)
Amortization of loss	377	419
Net other postretirement benefit cost	(378)	(257)
Other Postretirement [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	129	142
Interest cost on projected benefit obligation	417	469
Expected return on assets	(1,313)	(1,159)
Amortization of prior service cost (credit)	(186)	(186)
Amortization of loss	34	105
Net other postretirement benefit cost	(919)	(629)
Other Postretirement [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	330	372
Interest cost on projected benefit obligation	939	1,124
Expected return on assets	(2,446)	(2,180)
Amortization of prior service cost (credit)	(579)	(579)
Amortization of loss	206	826
Net other postretirement benefit cost	(1,550)	(437)
Other Postretirement [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	306	320
Interest cost on projected benefit obligation	500	559
Expected return on assets	(783)	(717)
Amortization of prior service cost (credit)	(378)	(378)
Amortization of loss	233	390
Net other postretirement benefit cost	(122)	174
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	8,900	4,600
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	132	105
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	50	48
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	80	64
Non Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	21	18
Non Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	$ 137	$ 127

Retirement And Other Postreti52

Retirement And Other Postretirement Benefits (Expected Employer Contributions) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Dec. 31, 2018
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	$ 91,800
Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		$ 352,100
Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	19,510
Entergy Louisiana [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		71,917
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		52,407
Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	4,194
Entergy Mississippi [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		14,933
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		10,739
Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	2,061
Entergy New Orleans [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		7,250
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		5,189
Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	3,873
Entergy Texas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		10,883
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		7,010
System Energy [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	3,715
System Energy [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		13,786
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		10,071
Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	$ 17,373
Entergy Arkansas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		64,062
Defined Benefit Plan Remaining Contributions To Be Made In Current Fiscal Year		$ 46,689

Retirement And Other Postreti53

Retirement And Other Postretirement Benefits (Reclassification Out Of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	$ 5,426	$ 6,562
Amortization of loss	(24,952)	(21,571)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(1,616)
Total	(21,142)	(15,009)
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,934	1,934
Amortization of loss	(1,257)	(1,332)
Total	677	602
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(99)	(65)
Amortization of loss	(21,957)	(18,450)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0
Total	(22,056)	(18,515)
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0
Amortization of loss	(867)	(865)
Total	(867)	(865)
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	5,595	6,717
Amortization of loss	(1,932)	(2,202)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0
Total	3,663	4,515
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,934	1,934
Amortization of loss	(388)	(465)
Total	1,546	1,469
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(70)	(90)
Amortization of loss	(1,063)	(919)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(1,616)
Total	(2,749)	(1,009)
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0
Amortization of loss	(2)	(2)
Total	$ (2)	$ (2)

Business Segment Information Bu

Business Segment Information Business Segment Information (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended	48 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2022
Segment Reporting Information [Line Items]
Asset Write-Offs, Impairments, And Related Charges	$ 72,924	$ 211,791
Restructuring Charges	26,000	24,000
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	$ 26,000	$ 24,000
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | Subsequent Event [Member]
Segment Reporting Information [Line Items]
Restructuring Charges			$ 165,000	$ 205,000

Business Segment Information (S

Business Segment Information (Segment Financial Information) (Details) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Segment Financial Information
Operating revenues		$ 2,723,881	$ 2,588,458
Income taxes (benefits)		43,663	7,763
Consolidated net income	[1]	136,200	86,051
Assets		47,281,525		$ 46,707,149
Utility [Member]
Segment Financial Information
Operating revenues		2,304,990	2,035,112
Income taxes (benefits)		52,224	98,492
Consolidated net income		217,940	167,623
Assets		43,690,561		42,978,669
Entergy Wholesale Commodities [Member]
Segment Financial Information
Operating revenues		418,924	553,367
Income taxes (benefits)		(1,078)	(78,337)
Consolidated net income		(17,779)	(27,197)
Assets		5,504,233		5,638,009
All Other [Member]
Segment Financial Information
Operating revenues		0	0
Income taxes (benefits)		(7,483)	(12,392)
Consolidated net income		(32,063)	(22,477)
Assets		834,463		1,011,612
Eliminations [Member]
Segment Financial Information
Operating revenues		(33)	(21)
Income taxes (benefits)		0	0
Consolidated net income		(31,898)	$ (31,898)
Assets		$ (2,747,732)		$ (2,921,141)
[1]	Text selection found with no content.

Business Segment Information 56

Business Segment Information Business Segment Information (Restructuring Costs) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017	Dec. 31, 2016
Segment Reporting Information [Line Items]
Restructuring Charges	$ 26	$ 24
Restructuring Reserve	123	115	$ 97	$ 91
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	26	24
Restructuring Reserve	109	94	83	70
Economic Development Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	0	0
Restructuring Reserve	$ 14	$ 21	$ 14	$ 21

Risk Management and Fair Valu57

Risk Management and Fair Values (Narrative) (Details) $ in Thousands, TWh in Millions	3 Months Ended		9 Months Ended	12 Months Ended
	Mar. 31, 2018USD ($)MMBTUGWhcounterparty	Mar. 31, 2017USD ($)	Dec. 31, 2018TWh	Dec. 31, 2017USD ($)counterparty
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount	$ 69,000			$ 34,000
Cash collateral posted	1,000			1,000
Derivative, Collateral, Obligation to Return Cash	6,000			4,000
Cash flow hedges relating to power sales as part of net unrealized gains	65,000
Reclassified from accumulated other comprehensive income (OCI) to operating revenues	41,000
Maturity of cash flow hedges, Tax	$ (6,000)	$ 18,000
Maximum length of time over which Company is currently hedging the variability in future cash flows for forecasted power transactions, years	3 years
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	63,890,000
Total volume of fixed transmission rights outstanding | GWh	18,490
Change in cash flow hedges due to ineffectiveness	$ 13,300	(1,000)
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset and Liability Unrealized Gains (Loss) Included in Earnings	200	400
Entergy Arkansas [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount	$ 200			200
Total volume of fixed transmission rights outstanding | GWh	4,153
Entergy Louisiana [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	53,730,000
Total volume of fixed transmission rights outstanding | GWh	8,162
Entergy Mississippi [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount	$ 100			100
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	10,160,000
Total volume of fixed transmission rights outstanding | GWh	2,562
Entergy New Orleans [Member]
Risk Management and Fair Values [Abstract]
Total volume of fixed transmission rights outstanding | GWh	943
Entergy Texas [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount	$ 200			50
Total volume of fixed transmission rights outstanding | GWh	2,541
Electricity Swaps And Options [Member]
Fair Value, Measurement With Unobservable Inputs Reconciliation, Recurring Basis, Asset and Liability, Realized Gain (Loss) Included In Earnings	$ 14,000	0
Fixed Transmission Rights (FTRs) [Member]
Fair Value, Measurement With Unobservable Inputs Reconciliation, Recurring Basis, Asset and Liability, Realized Gain (Loss) Included In Earnings	(1,000)	$ 0
Entergy Wholesale Commodities [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount				34,000
Cash collateral posted	500			1,000
Derivative, Collateral, Obligation to Return Cash	6,000			$ 4,000
Letters of Credit Held	$ 69,000
Number of Derivative Contract Counterparties in a Liability Position | counterparty	1			8
Dollar amount of hedge contract in a liability position	$ 300			$ 65,000
Subsequent Event [Member]
Risk Management and Fair Values [Abstract]
Planned generation sold forward from non utility nuclear power plants for the remainder of the period			98.00%
Planned Generation From Non Nuclear Power Plants Sold Forward Under Financial Hedges			79.00%
Total planned generation for remainder of the period | TWh			20.7

Risk Management and Fair Valu58

Risk Management and Fair Values (Fair Values Of Derivative Instruments) (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Derivatives, Fair Value [Line Items]
Cash collateral posted	$ 1,000	$ 1,000
Assets:
Derivative, Collateral, Obligation to Return Cash	6,000	4,000
Liabilities:
Letters of Credit Outstanding, Amount	69,000	34,000
Entergy Wholesale Commodities [Member]
Derivatives, Fair Value [Line Items]
Cash collateral posted	500	1,000
Assets:
Derivative, Collateral, Obligation to Return Cash	6,000	4,000
Liabilities:
Letters of Credit Outstanding, Amount		34,000
Other Non-Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	5,000	17,000
Derivative, Collateral, Right to Reclaim Cash	5,000	14,000
Derivative Liability	0	3,000
Other Deferred Debits And Other Assets [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	26,000	5,000
Derivative Asset, Fair Value, Gross Asset	31,000	19,000
Derivative, Collateral, Obligation to Return Cash	5,000	14,000
Prepayments And Other [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	49,000	0
Derivative Asset, Fair Value, Gross Asset	63,000	19,000
Derivative, Collateral, Obligation to Return Cash	14,000	19,000
Prepayments And Other [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0	0
Derivative Asset, Fair Value, Gross Asset	3,000	9,000
Derivative, Collateral, Obligation to Return Cash	3,000	9,000
Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Utility and Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	8,000	21,000
Derivative Asset, Fair Value, Gross Asset	9,000	22,000
Derivative, Collateral, Obligation to Return Cash	1,000	1,000
Other Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	13,000	86,000
Derivative, Collateral, Right to Reclaim Cash	13,000	20,000
Derivative Liability	0	66,000
Other Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	4,000	9,000
Derivative, Collateral, Right to Reclaim Cash	4,000	8,000
Derivative Liability	0	1,000
Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	1,000	6,000
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability	1,000	6,000
Entergy Louisiana [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	3,400	10,200
Derivative Asset, Fair Value, Gross Asset	3,800	11,000
Derivative, Collateral, Obligation to Return Cash	(400)	(800)
Entergy Louisiana [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	1,200	5,000
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability	1,200	5,000
Entergy Mississippi [Member]
Liabilities:
Letters of Credit Outstanding, Amount	100	100
Entergy Mississippi [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	900	2,100
Derivative Asset, Fair Value, Gross Asset	900	2,100
Derivative, Collateral, Obligation to Return Cash	0	0
Entergy Mississippi [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	200	1,200
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability	200	1,200
Entergy New Orleans [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	700	2,200
Derivative Asset, Fair Value, Gross Asset	700	2,200
Derivative, Collateral, Obligation to Return Cash	0	0
Entergy New Orleans [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		200
Derivative, Collateral, Right to Reclaim Cash		0
Derivative Liability		200
Entergy Arkansas [Member]
Liabilities:
Letters of Credit Outstanding, Amount	200	200
Entergy Arkansas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1,800	3,000
Derivative Asset, Fair Value, Gross Asset	1,900	3,200
Derivative, Collateral, Obligation to Return Cash	(100)	(200)
Entergy Texas [Member]
Liabilities:
Letters of Credit Outstanding, Amount	200	50
Entergy Texas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1,400	3,400
Derivative Asset, Fair Value, Gross Asset	1,400	3,600
Derivative, Collateral, Obligation to Return Cash	$ 0	$ (200)

Risk Management and Fair Valu59

Risk Management and Fair Values (Derivative Instruments Designated as Cash Flow Hedges On Consolidated Statements Of Income) (Details) - Competitive Businesses Operating Revenues [Member] - Electricity Swaps And Options [Member] - Cash Flow Hedging [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Effect of Derivative instruments designated as cash flow hedges on consolidated statements of income
Amount of gain (loss) recognized in AOCI (effective portion)	$ 91	$ 50
Amount of gain reclassified from accumulated OCI into income (effective portion)	$ (30)	$ 51

Risk Management and Fair Valu60

Risk Management and Fair Values (Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income) (Details) - Not Designated As Hedging Instrument [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Competitive Businesses Operating Revenues [Member] | Electricity Swaps And Options [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recognized in AOCI	$ 0	$ 9
Amount of gain (loss) recorded in income	1	0
Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recognized in AOCI	0	0
Amount of gain (loss) recorded in income	0	(7)
Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recognized in AOCI	0	0
Amount of gain (loss) recorded in income	32	30
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	8	4.6
Entergy Louisiana [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income		(6.1)
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	17.6	15.2
Entergy Mississippi [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	(0.2)	(1.1)
Entergy Mississippi [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	7.8	3.1
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)	(0.1)
Entergy New Orleans [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	3.3	2.4
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	$ (3.5)	$ 5.3

Risk Management and Fair Valu61

Risk Management and Fair Values (Assets And Liabilities At Fair Value On A Recurring Basis) (Details) - USD ($) $ in Millions		Mar. 31, 2018	Dec. 31, 2017
Assets at fair value on a recurring basis
Temporary cash investments		$ 1,148	$ 725
Assets other than temporary cash investments			7,212
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		8,797	8,414
Financial and Nonfinancial Liabilities, Fair Value Disclosure			76
Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		1	6
Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			70
Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		577	526
Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		2,619	2,550
Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		3,920	4,136
Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		75	5
Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		398	406
Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		52	45
Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		8	21
Fair Value Inputs Level 1 [Member]
Assets at fair value on a recurring basis
Temporary cash investments		1,148	725
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		3,259	2,827
Financial and Nonfinancial Liabilities, Fair Value Disclosure			6
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		1	6
Fair Value Inputs Level 1 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
Fair Value Inputs Level 1 [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		577	526
Fair Value Inputs Level 1 [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		1,084	1,125
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		398	406
Fair Value Inputs Level 1 [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		52	45
Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [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
Assets, Fair Value Disclosure		1,535	1,425
Financial and Nonfinancial Liabilities, Fair Value Disclosure			0
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Fair Value, Inputs, Level 2 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		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		1,535	1,425
Fair Value, Inputs, Level 2 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 2 [Member] | Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 2 [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
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
Assets, Fair Value Disclosure		83	26
Financial and Nonfinancial Liabilities, Fair Value Disclosure			70
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Fair Value, Inputs, Level 3 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			70
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		75	5
Fair Value, Inputs, Level 3 [Member] | Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 3 [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		8	21
Entergy Mississippi [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0.3	4.5
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		33.3	38.6
Entergy Mississippi [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0.2	1.2
Entergy Mississippi [Member] | Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		32.1	32
Entergy Mississippi [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0.9	2.1
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member]
Assets at fair value on a recurring basis
Temporary cash investments		0.3	4.5
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		32.4	36.5
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0.2	1.2
Entergy Mississippi [Member] | 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		32.1	32
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [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]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
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]
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		0.9	2.1
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Entergy Mississippi [Member] | 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
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0.9	2.1
Entergy Louisiana [Member]
Assets at fair value on a recurring basis
Temporary cash investments		561.9	30.1
Assets other than temporary cash investments			1,312.1
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		2,164.8	1,643.9
Entergy Louisiana [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		1.2	5
Entergy Louisiana [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	12.2	15.2
Entergy Louisiana [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	516.3	493.8
Entergy Louisiana [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	775.9	803.1
Entergy Louisiana [Member] | Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		285.6	289.5
Entergy Louisiana [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		9.5	2
Entergy Louisiana [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		3.4	10.2
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member]
Assets at fair value on a recurring basis
Temporary cash investments		561.9	30.1
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,014.8	480.1
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		1.2	5
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	12.2	15.2
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	145.6	143.3
Entergy Louisiana [Member] | 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		285.6	289.5
Entergy Louisiana [Member] | 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		9.5	2
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [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]
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		370.7	350.5
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	370.7	350.5
Entergy Louisiana [Member] | 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
Entergy Louisiana [Member] | 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
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [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]
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		3.4	10.2
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities [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]
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]
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]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		3.4	10.2
Entergy Arkansas [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments			944.9
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		945.4	954
Entergy Arkansas [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	3.6	11.7
Entergy Arkansas [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	350.8	348.2
Entergy Arkansas [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	581.3	585
Entergy Arkansas [Member] | Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments			2.4
Entergy Arkansas [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		7.9	3.7
Entergy Arkansas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		1.8	3
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		122.8	133.6
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	3.6	11.7
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	111.3	115.8
Entergy Arkansas [Member] | 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			2.4
Entergy Arkansas [Member] | 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		7.9	3.7
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [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]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		239.5	232.4
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	239.5	232.4
Entergy Arkansas [Member] | 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
Entergy Arkansas [Member] | 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
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [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]
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1.8	3
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities [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]
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]
Assets at fair value on a recurring basis
Assets other than temporary cash investments			0
Entergy Arkansas [Member] | 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
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		1.8	3
Entergy New Orleans [Member]
Assets at fair value on a recurring basis
Temporary cash investments		1.3	32.7
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		86.6	118.3
Entergy New Orleans [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0.2
Entergy New Orleans [Member] | Storm Reserve Escrow Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		79.8	81.9
Entergy New Orleans [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		4.8	1.5
Entergy New Orleans [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0.7	2.2
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member]
Assets at fair value on a recurring basis
Temporary cash investments		1.3	32.7
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		85.9	116.1
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0.2
Entergy New Orleans [Member] | 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		79.8	81.9
Entergy New Orleans [Member] | 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		4.8	1.5
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [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]
Assets at fair value on a recurring basis
Temporary cash investments		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Storm Reserve Escrow Account [Member]
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]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
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]
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		0.7	2.2
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Storm Reserve Escrow Account [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]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		0.7	2.2
Entergy Texas [Member]
Assets at fair value on a recurring basis
Temporary cash investments		39	115.5
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		70.1	156.6
Entergy Texas [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		29.7	37.7
Entergy Texas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		1.4	3.4
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member]
Assets at fair value on a recurring basis
Temporary cash investments		39	115.5
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		68.7	153.2
Entergy Texas [Member] | 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		29.7	37.7
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [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	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0	0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member] | Securitization Recovery Trust Account [Member]
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]
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	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1.4	3.4
Entergy Texas [Member] | 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
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments		1.4	3.4
System Energy [Member]
Assets at fair value on a recurring basis
Temporary cash investments		278.7	287.1
Assets other than temporary cash investments			905.7
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,174.9	1,192.8
System Energy [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	2.3	3.1
System Energy [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	325.6	330.5
System Energy [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	568.3	572.1
System Energy [Member] | Fair Value Inputs Level 1 [Member]
Assets at fair value on a recurring basis
Temporary cash investments		278.7	287.1
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		453.5	477.4
System Energy [Member] | Fair Value Inputs Level 1 [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	2.3	3.1
System Energy [Member] | Fair Value Inputs Level 1 [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	172.5	187.2
System Energy [Member] | 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
Assets, Fair Value Disclosure		153.1	143.3
System Energy [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	0	0
System Energy [Member] | Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	153.1	143.3
System Energy [Member] | 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
Assets, Fair Value Disclosure		0	0
System Energy [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities [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]
Assets at fair value on a recurring basis
Assets other than temporary cash investments	[1]	$ 0	$ 0
[1]	(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 9 to the financial statements herein for additional information on the investment portfolios.(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 Valu62

Risk Management and Fair Values (Reconciliation Of Changes In The Net Assets (Liabilities) For The Fair Value Of Derivatives Classified As Level 3 In The Fair Value Hierarchy) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
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	$ 14	$ 0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	(65)	5
Unrealized losses included in OCI	91	50
Included as a regulatory liability/asset	0	0
Settlements	35	(50)
Balance as of March 31,	75	5
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	(1)	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	21	21
Unrealized losses included in OCI	0	0
Included as a regulatory liability/asset	20	17
Settlements	(32)	(30)
Balance as of March 31,	8	8
Fixed Transmission Rights (FTRs) [Member] | Entergy Arkansas [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	3	5.4
Included as a regulatory liability/asset	6.8
Unrealized gains included as a regulatory liability/asset		0.1
Settlements	(8)	(4.6)
Balance as of March 31,	1.8	0.9
Fixed Transmission Rights (FTRs) [Member] | Entergy Louisiana [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	10.2	8.5
Included as a regulatory liability/asset	10.8
Unrealized gains included as a regulatory liability/asset		10.8
Settlements	(17.6)	(15.2)
Balance as of March 31,	3.4	4.1
Fixed Transmission Rights (FTRs) [Member] | Entergy Mississippi [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	2.1	3.2
Included as a regulatory liability/asset	6.6
Unrealized gains included as a regulatory liability/asset		1.2
Settlements	(7.8)	(3.1)
Balance as of March 31,	0.9	1.3
Fixed Transmission Rights (FTRs) [Member] | Entergy New Orleans [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	2.2	1.1
Included as a regulatory liability/asset	1.8
Unrealized gains included as a regulatory liability/asset		1.8
Settlements	(3.3)	(2.4)
Balance as of March 31,	0.7	0.5
Fixed Transmission Rights (FTRs) [Member] | Entergy Texas [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at Beginning of Period	3.4	3.1
Included as a regulatory liability/asset	(5.5)
Unrealized gains included as a regulatory liability/asset		3.2
Settlements	3.5	(5.3)
Balance as of March 31,	$ 1.4	$ 1

Risk Management and Fair Valu63

Risk Management and Fair Values (Schedules Of Valuation Techniques) (Details)	Mar. 31, 2018USD ($)
Fair Value of Electricity Swaps	$ 75,000,000
Maximum [Member]
Range from Average Percentage for Fair Value of Electricity Swaps	4.75%
Effect of Significant Unobservable Inputs on Fair Value of Electricity Swaps	$ 7,000,000
Minimum [Member]
Range from Average Percentage for Fair Value of Electricity Swaps	4.00%
Effect of Significant Unobservable Inputs on Fair Value of Electricity Swaps	$ 5

Decommissioning Trust Funds (Na

Decommissioning Trust Funds (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017	Jan. 01, 2018
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax				$ (632,617)
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 2,643,000		$ 2,539,000
Average coupon rate of debt securities	3.26%
Average duration of debt securities, years	6 years 66 days
Average maturity of debt securities, years	10 years 33 days
Proceeds from the dispositions of debt securities	$ 1,091,000	$ 514,000
Gains from dispositions of debt securities, gross	1,000	9,000
Losses from dispositions of debt securities, gross	7,000	5,000
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax			(17,000)
Equity Securities [Member]
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts			472,000
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	(64,000)		(1,000)
Debt Securities [Member]
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts	(2,000)		7,000
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	(48,000)		(16,000)
Entergy Arkansas [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 360,000		349,100
Average coupon rate of debt securities	2.67%
Average duration of debt securities, years	5 years 175 days
Average maturity of debt securities, years	6 years 329 days
Proceeds from the dispositions of debt securities	$ 34,900	36,000
Gains from dispositions of debt securities, gross	100	500
Losses from dispositions of debt securities, gross	0	100
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax			(3,000)
Entergy Arkansas [Member] | Equity Securities [Member]
Decommissioning Trust Funds [Abstract]
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	(8,000)		0
Entergy Arkansas [Member] | Debt Securities [Member]
Decommissioning Trust Funds [Abstract]
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	(9,700)		(3,000)
Entergy Louisiana [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 519,000		490,000
Average coupon rate of debt securities	3.83%
Average duration of debt securities, years	6 years 18 days
Average maturity of debt securities, years	11 years 310 days
Proceeds from the dispositions of debt securities	$ 125,500	40,600
Gains from dispositions of debt securities, gross	500	0
Losses from dispositions of debt securities, gross	$ 800	200
Percentage Interest in River Bend	30.00%
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax			(3,600)
Entergy Louisiana [Member] | Equity Securities [Member]
Decommissioning Trust Funds [Abstract]
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	$ (10,800)		0
Entergy Louisiana [Member] | Debt Securities [Member]
Decommissioning Trust Funds [Abstract]
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	(8,400)		(3,600)
System Energy [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 330,000		327,500
Average coupon rate of debt securities	2.72%
Average duration of debt securities, years	6 years 139 days
Average maturity of debt securities, years	9 years 141 days
Proceeds from the dispositions of debt securities	$ 54,200	75,800
Gains from dispositions of debt securities, gross	100	100
Losses from dispositions of debt securities, gross	600	$ 700
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax			(1,200)
System Energy [Member] | Equity Securities [Member]
Decommissioning Trust Funds [Abstract]
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	(7,800)		0
System Energy [Member] | Debt Securities [Member]
Decommissioning Trust Funds [Abstract]
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	(5,800)		(1,200)
Indian Point 3 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	789,000		798,000
Indian Point 1 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	485,000		491,000
Indian Point 2 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	614,000		621,000
Palisades [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	453,000		458,000
Pilgrim [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	1,048,000		1,068,000
Vermont Yankee [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	$ 591,000		$ 613,000

Decommissioning Trust Funds (Se

Decommissioning Trust Funds (Securities Held) (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Schedule of Available-for-sale Securities [Line Items]
Fair Value		$ 7,212
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		2,175
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax		17
Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value		4,662
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		2,131
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	$ 64	1
Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	2,619	2,550
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	23	44
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	48	16
Entergy Arkansas [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value		944.9
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		357
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax		3
Entergy Arkansas [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value		596.7
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		354.9
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	8	0
Entergy Arkansas [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	350.8	348.2
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	0.5	2.1
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	9.7	3
Entergy Louisiana [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value		1,312.1
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		472.1
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax		3.6
Entergy Louisiana [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value		818.3
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		461.2
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	10.8	0
Entergy Louisiana [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	516.3	493.8
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	5.7	10.9
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	8.4	3.6
System Energy [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value		905.7
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		312.8
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax		1.2
System Energy [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value		575.2
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax		308.6
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	7.8	0
System Energy [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Fair Value	325.6	330.5
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	1.4	4.2
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	$ 5.8	$ 1.2

Decommissioning Trust Funds (Av

Decommissioning Trust Funds (Available For Sale Securities Continuous Unrealized Loss Position Fair Value) (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value		$ 8
More than 12 months Fair Value		0
Total Fair Value		8
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss		1
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss		0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss		1
Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	$ 1,667	1,099
More than 12 months Fair Value	241	265
Total Fair Value	1,908	1,364
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	35	7
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	13	9
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	48	16
Entergy Arkansas [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value		0
More than 12 months Fair Value		0
Total Fair Value		0
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss		0
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss		0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss		0
Entergy Arkansas [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	277.8	168
More than 12 months Fair Value	42.5	41.4
Total Fair Value	320.3	209.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	7.2	1.2
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	2.5	1.8
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	9.7	3
Entergy Louisiana [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value		0
More than 12 months Fair Value		0
Total Fair Value		0
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss		0
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss		0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss		0
Entergy Louisiana [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	254.9	135.3
More than 12 months Fair Value	78.8	84.4
Total Fair Value	333.7	219.7
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	4.6	1.1
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	3.8	2.5
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	8.4	3.6
System Energy [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value		0
More than 12 months Fair Value		0
Total Fair Value		0
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss		0
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss		0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss		0
System Energy [Member] | Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Less than 12 months Fair Value	240.7	196.9
More than 12 months Fair Value	10.2	10.4
Total Fair Value	250.9	207.3
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	5.5	1
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.3	0.2
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	$ 5.8	$ 1.2

Decommissioning Trust Funds (Fa

Decommissioning Trust Funds (Fair Value Of Debt Securities By Contractual Maturities) (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Fair value of debt securities by contractual maturities
Less than 1 year	$ 89	$ 74
1 year - 5 years	928	902
5 years - 10 years	784	812
10 years - 15 years	152	147
15 years - 20 years	101	100
20 years+	565	515
Total	2,619	2,550
Entergy Arkansas [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	14.1	13
1 year - 5 years	130.6	123.4
5 years - 10 years	177.9	180.6
10 years - 15 years	3.4	4.8
15 years - 20 years	7	3.4
20 years+	17.8	23
Total	350.8	348.2
Entergy Louisiana [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	28.1	23.2
1 year - 5 years	136.7	122.8
5 years - 10 years	108.4	109.3
10 years - 15 years	52.9	52.7
15 years - 20 years	44.7	50.7
20 years+	145.5	135.1
Total	516.3	493.8
System Energy [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	5.5	4.1
1 year - 5 years	164.5	173
5 years - 10 years	78.4	78.5
10 years - 15 years	3.8	1
15 years - 20 years	10.7	6.9
20 years+	62.7	67
Total	$ 325.6	$ 330.5

Property, Plant, And Equipment

Property, Plant, And Equipment (Narrative) (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Construction expenditures in accounts payable	$ 280	$ 368
Entergy Arkansas [Member]
Construction expenditures in accounts payable	39.1	58.8
Entergy Louisiana [Member]
Construction expenditures in accounts payable	119.4	160.4
Entergy Mississippi [Member]
Construction expenditures in accounts payable	7.5	17.1
Entergy New Orleans [Member]
Construction expenditures in accounts payable	5.6	2.5
Entergy Texas [Member]
Construction expenditures in accounts payable	14.8	32.8
System Energy [Member]
Construction expenditures in accounts payable	$ 41.9	$ 33.9

Variable Interest Entities (Nar

Variable Interest Entities (Narrative) (Details) - Grand Gulf [Member] - System Energy [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Variable Interest Entity [Line Items]
Payments on lease, including interest	$ 8.6	$ 8.6
Percentage in power plant owned by VIE	11.50%

Revenue Recognition (Disaggrega

Revenue Recognition (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2018	Mar. 31, 2017
Electric Revenue		$ 2,248,262	$ 1,991,740
Gas Domestic Regulated Revenue		56,695	43,351
Competitive Energy Revenue		418,924	553,367
TOTAL		2,723,881	2,588,458
Residential [Member]
Electric Revenue		892,085
Commercial [Member]
Electric Revenue		595,720
Industrial [Member]
Electric Revenue		597,186
Governmental [Member]
Electric Revenue		56,478
Sales for Resale [Member]
Electric Revenue	[1]	69,526
Other Electric [Member]
Electric Revenue	[2]	27,433
Non-Customer [Member]
Electric Revenue	[3]	9,834
Competitive Energy Revenue	[3]	9,789
Competitive Business Sales [Member]
Competitive Energy Revenue	[1]	409,135
Retail [Member]
Electric Revenue		2,141,469
Entergy Arkansas [Member]
Electric Revenue		551,024	474,351
Gas Domestic Regulated Revenue		0
Entergy Arkansas [Member] | Residential [Member]
Electric Revenue		235,524
Entergy Arkansas [Member] | Commercial [Member]
Electric Revenue		120,634
Entergy Arkansas [Member] | Industrial [Member]
Electric Revenue		111,477
Entergy Arkansas [Member] | Governmental [Member]
Electric Revenue		4,648
Entergy Arkansas [Member] | Sales for Resale [Member]
Electric Revenue	[1]	66,103
Entergy Arkansas [Member] | Other Electric [Member]
Electric Revenue	[2]	10,024
Entergy Arkansas [Member] | Non-Customer [Member]
Electric Revenue	[3]	2,614
Entergy Arkansas [Member] | Retail [Member]
Electric Revenue		472,283
Entergy Louisiana [Member]
Electric Revenue		1,005,106	864,076
Gas Domestic Regulated Revenue		24,238	16,707
TOTAL		1,029,344	880,783
Entergy Louisiana [Member] | Residential [Member]
Electric Revenue		295,517
Entergy Louisiana [Member] | Commercial [Member]
Electric Revenue		224,928
Entergy Louisiana [Member] | Industrial [Member]
Electric Revenue		352,336
Entergy Louisiana [Member] | Governmental [Member]
Electric Revenue		17,310
Entergy Louisiana [Member] | Sales for Resale [Member]
Electric Revenue	[1]	89,255
Entergy Louisiana [Member] | Other Electric [Member]
Electric Revenue	[2]	20,503
Entergy Louisiana [Member] | Non-Customer [Member]
Electric Revenue	[3]	5,257
Entergy Louisiana [Member] | Retail [Member]
Electric Revenue		890,091
Entergy Mississippi [Member]
Electric Revenue		315,743	258,443
Gas Domestic Regulated Revenue		0
Entergy Mississippi [Member] | Residential [Member]
Electric Revenue		148,342
Entergy Mississippi [Member] | Commercial [Member]
Electric Revenue		110,460
Entergy Mississippi [Member] | Industrial [Member]
Electric Revenue		42,501
Entergy Mississippi [Member] | Governmental [Member]
Electric Revenue		10,848
Entergy Mississippi [Member] | Sales for Resale [Member]
Electric Revenue	[1]	1,993
Entergy Mississippi [Member] | Other Electric [Member]
Electric Revenue	[2]	(719)
Entergy Mississippi [Member] | Non-Customer [Member]
Electric Revenue	[3]	2,318
Entergy Mississippi [Member] | Retail [Member]
Electric Revenue		312,151
Entergy New Orleans [Member]
Electric Revenue		155,818	142,345
Gas Domestic Regulated Revenue		32,457	26,644
TOTAL		188,275	168,989
Entergy New Orleans [Member] | Residential [Member]
Electric Revenue		64,575
Entergy New Orleans [Member] | Commercial [Member]
Electric Revenue		54,272
Entergy New Orleans [Member] | Industrial [Member]
Electric Revenue		7,570
Entergy New Orleans [Member] | Governmental [Member]
Electric Revenue		17,691
Entergy New Orleans [Member] | Sales for Resale [Member]
Electric Revenue	[1]	13,337
Entergy New Orleans [Member] | Other Electric [Member]
Electric Revenue	[2]	(3,111)
Entergy New Orleans [Member] | Non-Customer [Member]
Electric Revenue	[3]	1,484
Entergy New Orleans [Member] | Retail [Member]
Electric Revenue		144,108
Entergy Texas [Member]
Electric Revenue		348,940	363,927
Gas Domestic Regulated Revenue		0
Entergy Texas [Member] | Residential [Member]
Electric Revenue		148,126
Entergy Texas [Member] | Commercial [Member]
Electric Revenue		85,427
Entergy Texas [Member] | Industrial [Member]
Electric Revenue		83,302
Entergy Texas [Member] | Governmental [Member]
Electric Revenue		5,981
Entergy Texas [Member] | Sales for Resale [Member]
Electric Revenue	[1]	23,361
Entergy Texas [Member] | Other Electric [Member]
Electric Revenue	[2]	2,264
Entergy Texas [Member] | Non-Customer [Member]
Electric Revenue	[3]	479
Entergy Texas [Member] | Retail [Member]
Electric Revenue		322,836
System Energy [Member]
Electric Revenue		$ 148,443	$ 154,787
[1]	(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.
[2]	(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.
[3]	(c)Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Revenue Recognition Revenue R71

Revenue Recognition Revenue Recognition (Narrative) (Details) - $ / MWh	3 Months Ended	60 Months Ended
	Mar. 31, 2018	Dec. 31, 2022
Subsequent Event [Member]
Maximum PPA price (per MWh)		61.50
System Energy [Member]
Percent Interest in Grand Gulf	90.00%

Asset Retirement Obligations 72

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

Uncategorized Items - etr-20180

Label	Element	Value
Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	$ 7,936,155,000
Treasury Stock [Member]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
Treasury Stock [Member] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	(5,397,637,000)
Additional Paid-in Capital [Member]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
Additional Paid-in Capital [Member] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	5,433,433,000
Common Stock [Member]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
Common Stock [Member] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	2,548,000
AOCI Attributable to Parent [Member]
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax	us-gaap_AccumulatedOtherComprehensiveIncomeLossFinancialLiabilityFairValueOptionAfterTax	(632,617,000)
AOCI Attributable to Parent [Member] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	(656,148,000)
Retained Earnings [Member]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	576,257,000	[1]
Retained Earnings [Member] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	8,553,959,000
Subsidiaries Preferred Stock [Member]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0	[1]
Subsidiaries Preferred Stock [Member] | Restatement Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest, Adjusted Balance	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterestAdjustedBalance1	$ 0
[1]	Text selection found with no content.