UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q



(Mark One)
X	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

	For the Quarterly Period Ended ~~June~~September 30, 2018
	OR
	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

	For the transition period from ____________ to ____________



Commission File Number	Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, Telephone Number, and IRS Employer Identification No.	Commission File Number	Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, Telephone Number, and IRS Employer Identification No.
1-11299	ENTERGY CORPORATION (a Delaware corporation) 639 Loyola Avenue New Orleans, Louisiana 70113 Telephone (504) 576-4000 72-1229752	1-35747	ENTERGY NEW ORLEANS, LLC (a Texas limited liability company) 1600 Perdido Street New Orleans, Louisiana 70112 Telephone (504) 670-3700 82-2212934


1-10764	ENTERGY ARKANSAS, INC. (an Arkansas corporation) 425 West Capitol Avenue Little Rock, Arkansas 72201 Telephone (501) 377-4000 71-0005900	1-34360	ENTERGY TEXAS, INC. (a Texas corporation) 10055 Grogans Mill Road The Woodlands, Texas 77380 Telephone (409) 981-2000 61-1435798


1-32718	ENTERGY LOUISIANA, LLC (a Texas limited liability company) 4809 Jefferson Highway Jefferson, Louisiana 70121 Telephone (504) 576-4000 47-4469646	1-09067	SYSTEM ENERGY RESOURCES, INC. (an Arkansas corporation) 1340 Echelon Parkway Jackson, Mississippi 39213 Telephone (601) 368-5000 72-0752777


1-31508	ENTERGY MISSISSIPPI, INC. (a Mississippi corporation) 308 East Pearl Street Jackson, Mississippi 39201 Telephone (601) 368-5000 64-0205830

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Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days. Yes þ No o

Indicate by check mark whether the registrants have submitted electronically ~~and posted on Entergy’s corporate Web site, if any,~~ every Interactive Data File required to be submitted ~~and posted~~ pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit ~~and post~~ such files). Yes þ No o

Indicate by check mark whether each registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Securities Exchange Act of 1934.



	Large accelerated filer	Accelerated filer	Non- accelerated filer	Smaller reporting company	Emerging growth company
Entergy Corporation	ü
Entergy Arkansas, Inc.			ü
Entergy Louisiana, LLC			ü
Entergy Mississippi, Inc.			ü
Entergy New Orleans, LLC			ü
Entergy Texas, Inc.			ü
System Energy Resources, Inc.			ü

If an emerging growth company, indicate by check mark if the registrants have elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act). Yes o No þ



Common Stock Outstanding		Outstanding at ~~July~~October 31, 2018
Entergy Corporation	($0.01 par value)	~~180,855,032~~181,142,215

Entergy Corporation, Entergy Arkansas, Inc., Entergy Louisiana, LLC, Entergy Mississippi, Inc., Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc. separately file this combined Quarterly Report on Form 10-Q. Information contained herein relating to any individual company is filed by such company on its own behalf. Each company reports herein only as to itself and makes no other representations whatsoever as to any other company. This combined Quarterly Report on Form 10-Q supplements and updates the Annual Report on Form 10‑K for the calendar year ended December 31, 2017 and the Quarterly ~~Report for~~Reports on Form 10-Q for the ~~quarter~~quarters ended March 31, 2018 and June 30, 2018, filed by the individual registrants with the SEC, and should be read in conjunction therewith.

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	Page Number

Forward-looking information	iii
Definitions	vi

Part I. Financial Information

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis	1
Consolidated Income Statements	2022
Consolidated Statements of Comprehensive Income	2123
Consolidated Statements of Cash Flows	2224
Consolidated Balance Sheets	2426
Consolidated Statements of Changes in Equity	2628
Selected Operating Results	2729
Notes to Financial Statements
Note 1. Commitments and Contingencies	2830
Note 2. Rate and Regulatory Matters	2931
Note 3. Equity	4146
Note 4. Revolving Credit Facilities, Lines of Credit, Short-term Borrowings, and Long-term Debt	4853
Note 5. Stock-based Compensation	5358
Note 6. Retirement and Other Postretirement Benefits	5460
Note 7. Business Segment Information	6167
Note 8. Risk Management and Fair Values	6369
Note 9. Decommissioning Trust Funds	8388
Note 10. Income Taxes	9096
Note 11. Property, Plant, and Equipment	9197
Note 12. Variable Interest Entities	9197
Note 13. Revenue Recognition	9298
Note 14. Asset Retirement Obligations	97102
Item 3. Quantitative and Qualitative Disclosures About Market Risk	98103
Item 4. Controls and Procedures	98103
Entergy Arkansas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis	99104
Consolidated Income Statements	~~107~~113
Consolidated Statements of Cash Flows	~~109~~115
Consolidated Balance Sheets	~~110~~116
Consolidated Statements of Changes in Common Equity	~~112~~118
Selected Operating Results	~~113~~119
Entergy Louisiana, LLC and Subsidiaries
Management’s Financial Discussion and Analysis	~~114~~120
Consolidated Income Statements	~~123~~130
Consolidated Statements of Comprehensive Income	~~124~~132
Consolidated Statements of Cash Flows	~~125~~133

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	Page Number

Consolidated Balance Sheets	~~126~~134
Consolidated Statements of Changes in Equity	~~128~~136
Selected Operating Results	~~129~~137
Entergy Mississippi, Inc.
Management’s Financial Discussion and Analysis	~~130~~138
Income Statements	~~137~~147
Statements of Cash Flows	~~139~~149
Balance Sheets	~~140~~150
Statements of Changes in Common Equity	~~142~~152
Selected Operating Results	~~143~~153
Entergy New Orleans, LLC and Subsidiaries
Management’s Financial Discussion and Analysis	~~144~~154
Consolidated Income Statements	~~152~~
~~Consolidated Statements of Cash Flows~~	~~153~~
~~Consolidated Balance Sheets~~	~~154~~
~~Consolidated Statements of Changes in Common Equity~~	~~156~~
~~Selected Operating Results~~	~~157~~
~~Entergy Texas, Inc. and Subsidiaries~~
~~Management’s Financial Discussion and Analysis~~	~~158~~
~~Consolidated Income Statements~~	~~164~~163
Consolidated Statements of Cash Flows	165
Consolidated Balance Sheets	166
Consolidated Statements of Changes in Common Equity	168
Selected Operating Results	169
~~System Energy Resources,~~Entergy Texas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis	170
Consolidated Income Statements	~~175~~177
Consolidated Statements of Cash Flows	179
Consolidated Balance Sheets	180
Consolidated Statements of Changes in Common Equity	182
Selected Operating Results	183
System Energy Resources, Inc.
Management’s Financial Discussion and Analysis	184
Income Statements	190
Statements of Cash Flows	~~177~~191
Balance Sheets	~~178~~192
Statements of Changes in Common Equity	~~180~~194

Part II. Other Information

Item 1. Legal Proceedings	~~181~~195
Item 1A. Risk Factors	~~181~~195
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	~~181~~195
Item 5. Other Information	~~182~~196
Item 6. Exhibits	~~185~~200
Signature	~~187~~202

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FORWARD-LOOKING INFORMATION

In this combined report and from time to time, Entergy Corporation and the Registrant Subsidiaries each makes statements as a registrant concerning its expectations, beliefs, plans, objectives, goals, strategies, and future events or performance. Such statements are “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. Words such as “may,” “will,” “could,” “project,” “believe,” “anticipate,” “intend,” “expect,” “estimate,” “continue,” “potential,” “plan,” “predict,” “forecast,” and other similar words or expressions are intended to identify forward-looking statements but are not the only means to identify these statements. Although each of these registrants believes that these forward-looking statements and the underlying assumptions are reasonable, it cannot provide assurance that they will prove correct. Any forward-looking statement is based on information current as of the date of this combined report and speaks only as of the date on which such statement is made. Except to the extent required by the federal securities laws, these registrants undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise.

Forward-looking statements involve a number of risks and uncertainties. There are factors that could cause actual results to differ materially from those expressed or implied in the forward-looking statements, including those factors discussed or incorporated by reference in (a) Item 1A. Risk Factors in the Form 10-K, (b) Management’s Financial Discussion and Analysis in the Form 10-K and in this report, and (c) the following factors (in addition to others described elsewhere in this combined report and in subsequent securities filings):

resolution of pending and future rate cases, formula rate proceedings and related negotiations, including various performance-based rate discussions, Entergy’s utility supply plan, and recovery of fuel and purchased power costs;

long-term risks and uncertainties associated with the termination of the System Agreement in 2016, including the potential absence of federal authority to resolve certain issues among the Utility operating companies and their retail regulators;

regulatory and operating challenges and uncertainties and economic risks associated with the Utility operating companies’ participation in MISO, including the benefits of continued MISO participation, the effect of current or projected MISO market rules and market and system conditions in the MISO markets, the allocation of MISO system transmission upgrade costs, and the effect of planning decisions that MISO makes with respect to future transmission investments by the Utility operating companies;

changes in utility regulation, including with respect to retail and wholesale competition, the ability to recover net utility assets and other potential stranded costs, and the application of more stringent transmission reliability requirements or market power criteria by the FERC or the U.S. Department of Justice;

changes in the regulation or regulatory oversight of Entergy’s nuclear generating facilities and nuclear materials and fuel, including with respect to the planned, potential, or actual shutdown of nuclear generating facilities owned or operated by Entergy Wholesale Commodities, and the effects of new or existing safety or environmental concerns regarding nuclear power plants and nuclear fuel;

resolution of pending or future applications, and related regulatory proceedings and litigation, for license renewals or modifications or other authorizations required of nuclear generating facilities and the effect of public and political opposition on these applications, regulatory proceedings, and litigation;

the performance of and deliverability of power from Entergy’s generation resources, including the capacity factors at Entergy’s nuclear generating facilities;

increases in costs and capital expenditures that could result from the commitment of substantial human and capital resources required for the operation and maintenance of Entergy’s nuclear generating facilities;

Entergy’s ability to develop and execute on a point of view regarding future prices of electricity, natural gas, and other energy-related commodities;

prices for power generated by Entergy’s merchant generating facilities and the ability to hedge, meet credit support requirements for hedges, sell power forward or otherwise reduce the market price risk associated with those facilities, including the Entergy Wholesale Commodities nuclear plants, especially in light of the planned shutdown or sale of each of these nuclear plants;

the prices and availability of fuel and power Entergy must purchase for its Utility customers, and Entergy’s ability to meet credit support requirements for fuel and power supply contracts;

iii

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FORWARD-LOOKING INFORMATION (Continued)

volatility and changes in markets for electricity, natural gas, uranium, emissions allowances, and other energy-related commodities, and the effect of those changes on Entergy and its customers;

changes in law resulting from federal or state energy legislation or legislation subjecting energy derivatives used in hedging and risk management transactions to governmental regulation;

changes in environmental laws and regulations, agency positions or associated litigation, including requirements for reduced emissions of sulfur dioxide, nitrogen oxide, greenhouse gases, mercury, particulate matter, heat, and other regulated air and water emissions, requirements for waste management and disposal and for the remediation of contaminated sites, wetlands protection and permitting, and changes in costs of compliance with these environmental laws and regulations;

changes in laws and regulations, agency positions, or associated litigation related to protected species and associated critical habitat designations;

the effects of changes in federal, state, or local laws and regulations, and other governmental actions or policies, including changes in monetary, fiscal, tax, environmental, trade/tariff, or energy policies;

uncertainty regarding the establishment of interim or permanent sites for spent nuclear fuel and nuclear waste storage and disposal and the level of spent fuel and nuclear waste disposal fees charged by the U.S. government or other providers related to such sites;

variations in weather and the occurrence of hurricanes and other storms and disasters, including uncertainties associated with efforts to remediate the effects of hurricanes, ice storms, or other weather events and the recovery of costs associated with restoration, including accessing funded storm reserves, federal and local cost recovery mechanisms, securitization, and insurance;

effects of climate change, including the potential for increases in sea levels or coastal land and wetland loss;

changes in the quality and availability of water supplies and the related regulation of water use and diversion;

Entergy’s ability to manage its capital projects and operation and maintenance costs;

Entergy’s ability to purchase and sell assets at attractive prices and on other attractive terms;

the economic climate, and particularly economic conditions in Entergy’s Utility service area and the northern United States and events and circumstances that could influence economic conditions in those areas, including power prices, and the risk that anticipated load growth may not materialize;

federal income tax reform, including the enactment of the Tax Cuts and Jobs Act, and its intended and unintended consequences on financial results and future cash flows, including the potential impact to credit ratings, which may affect Entergy’s ability to borrow funds or increase the cost of borrowing in the future;

the effects of Entergy’s strategies to reduce tax payments, especially in light of federal income tax reform;

changes in the financial markets and regulatory requirements for the issuance of securities, particularly as they affect access to capital and Entergy’s ability to refinance existing securities, execute share repurchase programs, and fund investments and acquisitions;

actions of rating agencies, including changes in the ratings of debt and preferred stock, changes in general corporate ratings, and changes in the rating agencies’ ratings criteria;

changes in inflation and interest rates;

the effect of litigation and government investigations or proceedings;

changes in technology, including (i) Entergy’s ability to implement new technologies, (ii) the impact of changes relating to new, developing, or alternative sources of generation such as distributed energy and energy storage, energy efficiency, demand side management, and other measures that reduce load, and (iii) competition from other companies offering products and services to ~~our~~Entergy’s customers based on new or emerging technologies;

the effects, including increased security costs, of threatened or actual terrorism, cyber-attacks or data security breaches, natural or man-made electromagnetic pulses that affect transmission or generation infrastructure, accidents, and war or a catastrophic event such as a nuclear accident or a natural gas pipeline explosion;

Entergy’s ability to attract and retain talented management, directors, and employees with specialized skills;

changes in accounting standards and corporate governance;

declines in the market prices of marketable securities and resulting funding requirements and the effects on benefits costs for Entergy’s defined benefit pension and other postretirement benefit plans;

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FORWARD-LOOKING INFORMATION (Concluded)

future wage and employee benefit costs, including changes in discount rates and returns on benefit plan assets;

changes in decommissioning trust fund values or earnings or in the timing of, requirements for, or cost to decommission Entergy’s nuclear plant sites and the implementation of decommissioning of such sites following shutdown;

the decision to cease merchant power generation at all Entergy Wholesale Commodities nuclear power plants by mid-2022, including the implementation of the planned shutdowns of Pilgrim, Indian Point 2, Indian Point 3, and Palisades;

the effectiveness of Entergy’s risk management policies and procedures and the ability and willingness of its counterparties to satisfy their financial and performance commitments;

factors that could lead to impairment of long-lived assets; and

the ability to successfully complete strategic transactions Entergy may undertake, including mergers, acquisitions, divestitures, or restructurings, regulatory or other limitations imposed as a result of any such strategic transaction, and the success of the business following any such strategic transaction.

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DEFINITIONS

Certain abbreviations or acronyms used in the text and notes are defined below:



Abbreviation or Acronym	Term

ALJ	Administrative Law Judge
ANO 1 and 2	Units 1 and 2 of Arkansas Nuclear One (nuclear), owned by Entergy Arkansas
APSC	Arkansas Public Service Commission
ASU	Accounting Standards Update issued by the FASB
Board	Board of Directors of Entergy Corporation
Cajun	Cajun Electric Power Cooperative, Inc.
capacity factor	Actual plant output divided by maximum potential plant output for the period
City Council	Council of the City of New Orleans, Louisiana
D.C. Circuit	U.S. Court of Appeals for the District of Columbia Circuit
DOE	United States Department of Energy
Entergy	Entergy Corporation and its direct and indirect subsidiaries
Entergy Corporation	Entergy Corporation, a Delaware corporation
Entergy Gulf States, Inc.	Predecessor company for financial reporting purposes to Entergy Gulf States Louisiana that included the assets and business operations of both Entergy Gulf States Louisiana and Entergy Texas
Entergy Gulf States Louisiana	Entergy Gulf States Louisiana, L.L.C., a Louisiana limited liability company formally created as part of the jurisdictional separation of Entergy Gulf States, Inc. and the successor company to Entergy Gulf States, Inc. for financial reporting purposes. The term is also used to refer to the Louisiana jurisdictional business of Entergy Gulf States, Inc., as the context requires. Effective October 1, 2015, the business of Entergy Gulf States Louisiana was combined with Entergy Louisiana.
Entergy Louisiana	Entergy Louisiana, LLC, a Texas limited liability company formally created as part of the combination of Entergy Gulf States Louisiana and the company formerly known as Entergy Louisiana, LLC (Old Entergy Louisiana) into a single public utility company and the successor to Old Entergy Louisiana for financial reporting purposes.
Entergy Texas	Entergy Texas, Inc., a Texas corporation formally created as part of the jurisdictional separation of Entergy Gulf States, Inc. The term is also used to refer to the Texas jurisdictional business of Entergy Gulf States, Inc., as the context requires.
Entergy Wholesale Commodities	Entergy’s non-utility business segment primarily comprised of the ownership, operation, and decommissioning of nuclear power plants, the ownership of interests in non-nuclear power plants, and the sale of the electric power produced by its operating power plants to wholesale customers
EPA	United States Environmental Protection Agency
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
FitzPatrick	James A. FitzPatrick Nuclear Power Plant (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which was sold in March 2017
Form 10-K	Annual Report on Form 10-K for the calendar year ended December 31, 2017 filed with the SEC by Entergy Corporation and its Registrant Subsidiaries
Grand Gulf	Unit No. 1 of Grand Gulf Nuclear Station (nuclear), 90% owned or leased by System Energy
GWh	Gigawatt-hour(s), which equals one million kilowatt-hours
Independence	Independence Steam Electric Station (coal), owned 16% by Entergy Arkansas, 25% by Entergy Mississippi, and 7% by Entergy Power, LLC

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DEFINITIONS (Continued)



Abbreviation or Acronym	Term

Indian Point 2	Unit 2 of Indian Point Energy Center (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
Indian Point 3	Unit 3 of Indian Point Energy Center (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
IRS	Internal Revenue Service
ISO	Independent System Operator
kW	Kilowatt, which equals one thousand watts
kWh	Kilowatt-hour(s)
LPSC	Louisiana Public Service Commission
MISO	Midcontinent Independent System Operator, Inc., a regional transmission organization
MMBtu	One million British Thermal Units
MPSC	Mississippi Public Service Commission
MW	Megawatt(s), which equals one thousand kilowatts
MWh	Megawatt-hour(s)
Net debt to net capital ratio	Gross debt less cash and cash equivalents divided by total capitalization less cash and cash equivalents
Net MW in operation	Installed capacity owned and operated
NRC	Nuclear Regulatory Commission
NYPA	New York Power Authority
Palisades	Palisades Nuclear Plant (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
Parent & Other	The portions of Entergy not included in the Utility or Entergy Wholesale Commodities segments, primarily consisting of the activities of the parent company, Entergy Corporation
Pilgrim	Pilgrim Nuclear Power Station (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
PPA	Purchased power agreement or power purchase agreement
PUCT	Public Utility Commission of Texas
Registrant Subsidiaries	Entergy Arkansas, Inc., Entergy Louisiana, LLC, Entergy Mississippi, Inc., Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc.
River Bend	River Bend Station (nuclear), owned by Entergy Louisiana
SEC	Securities and Exchange Commission
System Agreement	Agreement, effective January 1, 1983, as modified, among the Utility operating companies relating to the sharing of generating capacity and other power resources. The agreement terminated effective August 2016.
System Energy	System Energy Resources, Inc.
TWh	Terawatt-hour(s), which equals one billion kilowatt-hours
Unit Power Sales Agreement	Agreement, dated as of June 10, 1982, as amended and approved by the FERC, among Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy, relating to the sale of capacity and energy from System Energy’s share of Grand Gulf
Utility	Entergy’s business segment that generates, transmits, distributes, and sells electric power, with a small amount of natural gas distribution
Utility operating companies	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas

vii

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DEFINITIONS (Concluded)



Abbreviation or Acronym	Term

Vermont Yankee	Vermont Yankee Nuclear Power Station (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in December 2014
Waterford 3	Unit No. 3 (nuclear) of the Waterford Steam Electric Station, 100% owned or leased by Entergy Louisiana
weather-adjusted usage	Electric usage excluding the effects of deviations from normal weather
White Bluff	White Bluff Steam Electric Generating Station, 57% owned by Entergy Arkansas

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ENTERGY CORPORATION AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Entergy operates primarily through two business segments: Utility and Entergy Wholesale Commodities.

The Utility business segment 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.

The Entergy Wholesale Commodities business segment 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. See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for discussion of the operation and planned shutdown or sale of each of the Entergy Wholesale Commodities nuclear power plants.

See Note 7 to the financial statements herein for financial information regarding Entergy’s business segments.

Results of Operations

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter 2017

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the ~~second~~third quarter 2018 to the ~~second~~third quarter 2017 showing how much the line item increased or (decreased) in comparison to the prior period:


	Utility			Entergy Wholesale Commodities			Parent & Other (a)			Entergy			Utility			Entergy Wholesale Commodities			Parent & Other (a)			Entergy
	(In Thousands)												(In Thousands)
2nd Quarter 2017 Consolidated Net Income (Loss)		$246,382			$223,886			($56,900	)		$413,368
3rd Quarter 2017 Consolidated Net Income (Loss)														$403,733			$55,765			($57,854	)		$401,644

Net revenue (operating revenue less fuel expense, purchased power, and other regulatory charges/credits)	(179,032		)	22,121			(2		)	(156,913		)	(253,847		)	(50,681		)	(2		)	(304,530		)
Other operation and maintenance	31,127			8,895			5,114			45,136			50,746			24,903			3,363			79,012
Asset write-offs, impairments, and related charges	—			(124,628		)	—			(124,628		)	—			138,994			—			138,994
Taxes other than income taxes	1,796			3,465			22			5,283			1,388			775			279			2,442
Depreciation and amortization	13,564			(13,350		)	(57		)	157			(17,013		)	(12,845		)	(253		)	(30,111		)
Other income	(11,092		)	(3,715		)	(1,151		)	(15,958		)	26,926			88,207			(624		)	114,509
Interest expense	5,208			2,410			7,174			14,792			2,256			3,386			7,526			13,168
Other expenses	(2,656		)	(2,963		)	—			(5,619		)	(628		)	(6,271		)	—			(6,899		)
Income taxes	(371,175		)	424,800			2,891			56,516			(367,682		)	(161,222		)	4,103			(524,801		)

2nd Quarter 2018 Consolidated Net Income (Loss)		$378,394			($56,337	)		($73,197	)		$248,860
3rd Quarter 2018 Consolidated Net Income (Loss)														$507,745			$105,571			($73,498	)		$539,818


(a)	Parent & Other includes eliminations, which are primarily intersegment activity.

Refer to “ENTERGY CORPORATION AND SUBSIDIARIES - SELECTED OPERATING RESULTS” for further information with respect to operating statistics.

~~Second~~Third quarter 2018 results of operations includes impairment charges of ~~$69~~$155 million ($54123 million net-of-tax) due to costs being charged directly to expense as a result of the impaired value of the Entergy Wholesale ~~Commodities~~

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

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, ~~and~~ a ~~$52~~$107 million reduction of income tax ~~benefit~~expense, recognized by Entergy ~~Louisiana,~~Wholesale Commodities, as a result of ~~the settlement~~a restructuring of the ~~2012-2013 IRS audit, associated with the Hurricane Katrina~~investment holdings in one of its nuclear plant decommissioning trust funds, and ~~Hurricane Rita contingent sharing obligation associated with the Louisiana Act 55 financing.~~a $23 million reduction of income tax expense, recognized by Entergy Wholesale Commodities, as a result of a state income tax audit. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. See Note 10 to the financial statements herein for discussion of the ~~IRS~~state income tax audit ~~settlement.~~and restructuring of its interest in the decommissioning trust fund.

~~Second~~Net Revenue

Utility

Following is an analysis of the change in net revenue comparing the third quarter ~~2017 results~~2018 to the third quarter 2017:



	Amount
	(In Millions)
2017 net revenue		$1,811
Return of unprotected excess accumulated deferred income taxes to customers	(277		)
Grand Gulf recovery	(39		)
Retail electric price	(8		)
Volume/weather	44
Net wholesale revenue	26
2018 net revenue		$1,557

The return of ~~operations include~~unprotected excess accumulated deferred income taxes to customers resulted from activity in the third quarter 2018 at Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy in response to the enactment of the Tax Cuts and Jobs Act. There is no effect on net income as the reductions in net revenue were offset by reductions in income tax expense. Entergy Texas’s proposal for the return of its unprotected excess accumulated deferred income taxes is pending before the PUCT in an unopposed settlement in its base rate case proceeding. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

The Grand Gulf recovery variance is primarily due to a reduction in depreciation expense recognized in third quarter 2018 upon FERC approval of the settlement in the Unit Power Sales Agreement proceeding, a reduction in income tax expense ~~net~~associated with the reduction in the federal income tax rate in 2018, and a reduction in recoverable decommissioning costs, primarily attributable to increased earnings on the decommissioning trust funds. This was partially offset by increases in other capacity costs. See Note 2 to the financial statements herein for a discussion of ~~unrecognized tax~~the Unit Power Sales Agreement settlement. See Note 3 to the financial statements in the Form 10-K for a discussion of the Tax Cut and Jobs Act.

The retail electric price variance is primarily due to regulatory charges recorded in the third quarter 2018 to reflect the effects of regulatory agreements to return the benefits of ~~$373 million~~the lower income tax rate in 2018 to customers in Louisiana and New Orleans and a decrease in formula rate plan revenues implemented with the first billing cycle of September 2017 at Entergy Louisiana. The decrease was substantially offset by an increase in formula rate plan rates effective with the first billing cycle of January 2018 at Entergy Arkansas, as ~~a result of a change~~approved by the APSC, and an increase in energy efficiency revenues. See Note 2 to the financial statements herein and in the ~~tax classification~~Form 10-K for further discussion of ~~legal entities that own~~ the regulatory proceedings.

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Entergy ~~Wholesale Commodities nuclear power plants~~Corporation and ~~$194 million ($126 million net-of-tax) of impairment charges~~Subsidiaries

Management's Financial Discussion and Analysis

The volume/weather variance is primarily due to ~~costs being charged directly to expense~~an increase of 1,851 GWh, or 6%, in billed electricity usage, including the effect of more favorable weather on residential and commercial sales and an increase in industrial usage. The increase in industrial usage is primarily driven by small industrials and cogeneration sales, as well as continued growth from new and expansion customers. The increase was partially offset by the effect of less favorable weather during the unbilled sales period.

The net wholesale revenue variance is primarily because of the regulatory lag experienced by certain Utility operating companies as a result of the ~~impaired value~~change in the federal income tax rate in 2018 and its effect on wholesale rates. See Note 2 herein and in the Form 10-K for discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

Entergy Wholesale Commodities

Following is an analysis of the change in net revenue comparing the third quarter 2018 to the third quarter 2017:



	Amount
	(In Millions)
2017 net revenue		$392
Nuclear realized price changes	(24		)
Nuclear volume	(14		)
Other	(13		)
2018 net revenue		$341

As shown in the table above, net revenue for Entergy Wholesale Commodities decreased by $51 million in the third quarter2018 as compared to the third quarter 2017 primarily due to lower realized wholesale energy prices, partially offset by higher capacity prices, and lower volume in the Entergy Wholesale Commodities nuclear ~~plants’ long-lived assets~~fleet resulting from more non-refueling outage days in the third quarter 2018 as compared to the third quarter 2017.

Following are key performance measures for Entergy Wholesale Commodities for the third quarter2018 and 2017:



	2018	2017
Owned capacity (MW)	3,962	3,962
GWh billed	7,576	8,234

Entergy Wholesale Commodities Nuclear Fleet (a)
Capacity factor	90%	98%
GWh billed	6,976	7,633
Average energy price ($/MWh)	$38.01	$39.94
Average capacity price ($/kW-month)	$9.32	$9.09


(a)	The Entergy Wholesale Commodities nuclear power plants had no refueling outage days in the third quarter 2018 or the third quarter 2017.

Other Income Statement Items

Utility

Other operation and maintenance expenses increased from $584 million for the third quarter 2017 to $635 million for the third quarter 2018 primarily due to:

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an increase of $16 million in fossil-fueled generation expenses primarily due to an overall higher scope of work performed in third quarter 2018 as compared to third quarter 2017;

an increase of $15 million in energy efficiency costs;

an increase of $8 million in customer service costs primarily due to higher contract costs;

an increase of $7 million in information technology costs primarily due to higher software maintenance costs and higher contract costs; and

a $6 million loss in 2018 on the ~~significantly reduced remaining estimated operating lives associated with~~sale of fuel oil inventory per an agreement approved by the MPSC in June 2018 resulting from the stipulation related to the effects of the Tax Act. There is no effect on net income as the loss on the sale of fuel oil inventory is offset by a reduction in income tax expense.

Depreciation and amortization expenses decreased primarily due to updated depreciation rates used in calculating Grand Gulf plant depreciation and amortization expenses under the Unit Power Sales Agreement as part of a settlement approved by the FERC in August 2018. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the Unit Power Sales Agreement.

Entergy Wholesale Commodities

Other operation and maintenance expenses increased from $184 million for the third quarter 2017 to $209 million for the third quarter 2018 primarily due to an increase of $19 million in severance and retention costs as a result of management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. See ~~Note 3 to the financial statements in the Form 10-K for additional discussion of the tax elections and~~ “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet.

~~Net Revenue~~

~~Utility~~

~~Following is an analysis of the change in net revenue comparing the second quarter 2018 to the second quarter 2017:~~



	~~Amount~~
	~~(In Millions)~~
~~2017 net revenue~~		~~$1,549~~
~~Return of unprotected excess accumulated deferred income taxes to customers~~	~~(278~~		)
~~Grand Gulf recovery~~	~~(17~~		)
~~Retail electric price~~	(2		)
~~Volume/weather~~	~~101~~
~~Other~~	17
~~2018 net revenue~~		~~$1,370~~

The return of unprotected excess accumulated deferred income taxes to customers resulted from activity at Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and System Energy in response to the enactment of the Tax Cuts and Jobs Act. There is no effect on net income as the reductions in net revenue were offset by reductions in income tax expense. Entergy New Orleans will begin returning its unprotected excess accumulated deferred income taxes in the third quarter 2018 and Entergy Texas’s proposal for the return of its unprotected excess accumulated deferred income taxes is pending. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

~~The Grand Gulf recovery variance is primarily due to recovery of lower operating costs.~~

The retail electric price variance is primarily due to regulatory charges recorded in the second quarter 2018 to reflect the effects of regulatory agreements to return the benefits of the lower income tax rate in 2018 to customers in Louisiana and New Orleans. The decrease was substantially offset by the following:

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~~an increase in formula rate plan rates effective with the first billing cycle of January 2018 at Entergy Arkansas, as approved by the APSC;~~

~~higher storm damage rider revenues at Entergy Mississippi;~~

~~an increase in energy efficiency revenues; and~~

~~increases in the distribution cost recovery factor rider rate in September 2017 at Entergy Texas, as approved by the PUCT.~~

~~See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the regulatory proceedings discussed above.~~

The volume/weather variance is primarily due to an increase of 479 GWh, or 2%, in billed electricity usage, including the effect of more favorable weather on residential and commercial sales and the effect of more favorable weather during the unbilled sales period.

~~Entergy Wholesale Commodities~~

~~Following is an analysis of the change in net revenue comparing the second quarter~~ ~~2018~~ ~~to the second quarter 2017:~~



	~~Amount~~
	~~(In Millions)~~
~~2017 net revenue~~		~~$250~~
~~Nuclear volume~~	61
~~Nuclear realized price changes~~	~~(38~~		)
~~Other~~	(1		)
~~2018 net revenue~~		~~$272~~

~~As shown in the table above, net revenue for Entergy Wholesale Commodities increased by $22 million in the second quarter~~2018 as compared to the second quarter 2017 primarily due to higher volume in the Entergy Wholesale Commodities nuclear fleet resulting from fewer refueling outage days in the second quarter 2018 as compared to the second quarter 2017. The increase was partially offset by lower realized wholesale energy prices and the effect of rising forward power prices on electricity derivative instruments that are not designated as hedging instruments, partially offset by higher capacity prices.

~~Following are key performance measures for Entergy Wholesale Commodities for the second quarter2018 and 2017:~~

2018 2017
Owned capacity (MW) 3,962 3,962
GWh billed 7,281 6,019

Entergy Wholesale Commodities Nuclear Fleet
Capacity factor 86% 59%
GWh billed 6,713 5,393
Average energy and capacity revenue per MWh $41.82 $51.76
Refueling outage days:
Indian Point 2 20 —
Indian Point 3 — 47
Pilgrim — 43
Palisades — 27

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~~Other Income Statement Items~~

~~Utility~~

~~Other operation and maintenance expenses increased from $598 million for the second quarter 2017 to $629 million for the second quarter 2018 primarily due to:~~

~~an increase of $17 million in fossil-fueled generation expenses primarily due to~~ ~~an overall higher scope of work performed during outages in second quarter 2018 as compared to second quarter 2017;~~

~~an increase of $5 million in energy efficiency costs; and~~

~~an increase of $5 million in storm damage provisions, primarily at Entergy Mississippi.~~ ~~See Note 2 to the financial statements herein and in the Form 10-K for a discussion of storm cost recovery.~~

~~Depreciation and amortization expenses increased primarily due to additions to plant in service.~~

Other income decreased primarily due to changes in decommissioning trust fund investment activity, including portfolio rebalancing of certain of the decommissioning trust funds in the second quarter 2017. The decrease was partially offset by an increase in the allowance for equity funds used during construction due to higher construction work in progress in 2018, which included the St. Charles Power Station project.

~~Entergy Wholesale Commodities~~

The asset write-offs, impairments, and related charges variance is primarily due to impairment charges of ~~$69~~$155 million ($54123 million net-of-tax) in the ~~second~~third quarter 2018 compared to impairment charges of ~~$194~~$16 million ($~~126~~10 million net-of-tax) in the ~~second~~third quarter 2017. The impairment charges are due to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets being 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. The ~~decrease~~increase in impairment charges in ~~second~~the third quarter 2018 is primarily due to ~~Palisades expenditures incurred after September 30, 2017 no longer being charged~~$117 million ($93 million net-of-tax) of impairment charges related to ~~expense as incurred but recorded as assets and depreciated or amortized and~~Pilgrim primarily resulting from the ~~timing~~effects of ~~nuclear refueling outage spending at the remaining impaired Entergy Wholesale Commodities nuclear plants.~~an updated decommissioning cost study. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. See Note 14 to the financial statements herein for a discussion of asset retirement obligations. See Note 14 to the financial statements in the Form 10-K for a discussion of impairment of long-lived assets.

Depreciation and amortization expenses decreased primarily due to the decision in the third quarter 2017 to continue operating Palisades until May 31, 2022. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” in the Form 10-K for a discussion of the planned shutdown of Palisades.

Other income increased primarily due to higher realized gains on the decommissioning trust fund investments in the third quarter 2018 as compared to the third quarter 2017, including the effect of portfolio rebalancing in the third quarter 2018.

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Income Taxes

The effective income tax rate was ~~884.2%~~(110.2%) for the ~~second~~third quarter 2018. The difference in the effective income tax rate for the ~~second~~third quarter 2018 versus the federal statutory rate of 21% was primarily due to amortization of excess accumulated deferred income taxes, a restructuring of the investment holdings in one of the Entergy Wholesale Commodities’ nuclear plant decommissioning trusts for which additional tax basis is now recoverable, and ~~an IRS~~the conclusion of a state income tax audit ~~settlement for the 2012-2013 tax returns.~~involving Entergy Wholesale Commodities. See Notes 2 and 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 10 to the financial statements herein for ~~a discussion~~discussions of the ~~IRS audit settlement.~~restructuring and the conclusion of the state income tax audit.

The effective income tax rate was ~~(442.1%)~~37.6% for the ~~second~~third quarter 2017. The difference in the effective income tax rate for the ~~second~~third quarter 2017 versus the federal statutory rate of 35% was primarily due to ~~a change in the~~state income taxes, partially offset by book and tax

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~~classification of legal entities that own Entergy Wholesale Commodities nuclear power plants, which resulted in both permanent and temporary~~ differences ~~under the income tax accounting standards. See Note 3~~related to the ~~financial statements in the Form 10-K~~allowance for ~~further discussion of the change in tax classification.~~equity funds used during construction.

~~Six~~Nine Months Ended ~~June~~September 30, 2018 Compared to ~~Six~~Nine Months Ended ~~June~~September 30, 2017

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the ~~six~~nine months ended ~~June~~September 30, 2018 to the ~~six~~nine months ended ~~June~~September 30, 2017 showing how much the line item increased or (decreased) in comparison to the prior period:


	Utility			Entergy Wholesale Commodities			Parent & Other (a)			Entergy			Utility			Entergy Wholesale Commodities			Parent & Other (a)			Entergy
	(In Thousands)												(In Thousands)
2017 Consolidated Net Income (Loss)		$414,005			$196,689			($111,274	)		$499,420			$817,738			$252,455			($169,129	)		$901,064

Net revenue (operating revenue less fuel expense, purchased power, and other regulatory charges/credits)	(123,626		)	(90,167		)	(12		)	(213,805		)	(377,472		)	(140,849		)	(13		)	(518,334		)
Other operation and maintenance	61,999			(85,218		)	5,081			(18,138		)	114,009			(61,579		)	8,444			60,874
Asset write-offs, impairments, and related charges	—			(263,495		)	—			(263,495		)	—			(124,502		)	—			(124,502		)
Taxes other than income taxes	17,089			(3,112		)	172			14,149			18,478			(2,337		)	451			16,592
Depreciation and amortization	27,672			(27,794		)	—			(122		)	10,660			(40,640		)	(253		)	(30,233		)
Gain on sale of assets	—			(16,270		)	—			(16,270		)	—			(16,270		)	—			(16,270		)
Other income	458			(61,088		)	(1,839		)	(62,469		)	28,651			25,853			(2,464		)	52,040
Interest expense	7,192			4,232			10,979			22,403			9,449			7,618			18,504			35,571
Other expenses	(2,005		)	(23,392		)	—			(25,397		)	(2,633		)	(29,664		)	—			(32,297		)
Income taxes	(417,443		)	502,059			7,801			92,417			(785,124		)	340,837			11,905			(432,382		)

2018 Consolidated Net Income (Loss)		$596,333			($74,116	)		($137,158	)		$385,059			$1,104,078			$31,456			($210,657	)		$924,877


(a)	Parent & Other includes eliminations, which are primarily intersegment activity.

Refer to “ENTERGY CORPORATION AND SUBSIDIARIES - SELECTED OPERATING RESULTS” for further information with respect to operating statistics.

Results of operations for the ~~six~~nine months ended ~~June~~September 30, 2018 include impairment charges of ~~$142~~$297 million ($~~112~~235 million net-of-tax) due to costs being charged directly to expense 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, a $107 million reduction of income tax expense, recognized by Entergy Wholesale Commodities, as a

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result of a restructuring of the investment holdings in one of its nuclear plant decommissioning trust funds, a $52 million income tax benefit, recognized by Entergy Louisiana, as a result of the settlement of the 2012-2013 IRS audit, associated with the Hurricane Katrina and Hurricane Rita contingent sharing obligation associated with the Louisiana Act 55 ~~financing.~~financing, and a $23 million reduction of income tax expense, recognized by Entergy Wholesale Commodities, as a result of a state income tax audit. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. See Note 10 to the financial statements herein for discussion of the IRS audit ~~settlement.~~settlement, the state income tax audit, and restructuring of its interest in the decommissioning trust fund.

Results of operations for the ~~six~~nine months ended ~~June~~September 30, 2017 include impairment charges of ~~$405~~$422 million ($~~263~~274 million net-of-tax) due to costs being charged directly to expense 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 and a reduction of income tax expense, net of unrecognized tax benefits, of $373 million as a result of a change in the

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tax classification of legal entities that own Entergy Wholesale Commodities nuclear power plants. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet and Note 3 to the financial statements in the Form 10-K for additional discussion of the tax elections.

Net Revenue

Utility

Following is an analysis of the change in net revenue comparing the ~~six~~nine months ended ~~June~~September 30, 2018 to the ~~six~~nine months ended ~~June~~September 30, 2017:



	Amount
	(In Millions)
2017 net revenue		$~~2,954~~4,765
Return of unprotected excess accumulated deferred income taxes to customers	(~~278~~555		)
Grand Gulf recovery	(3574		)
Retail electric price	5(4		)
Net wholesale revenue	35
Volume/weather	~~159~~203
Other	2518
2018 net revenue		$~~2,830~~4,388

The return of unprotected excess accumulated deferred income taxes to customers resulted from activity in 2018 at Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy in response to the enactment of the Tax Cuts and Jobs Act. There is no effect on net income as the reductions in net revenue were offset by reductions in income tax expense. Entergy ~~New Orleans will begin returning its unprotected excess accumulated deferred income taxes in the third quarter 2018 and Entergy~~ Texas’s proposal for the return of its unprotected excess accumulated deferred income taxes is ~~pending.~~pending before the PUCT in an unopposed settlement in its base rate case proceeding. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

The Grand Gulf recovery variance is primarily due to ~~recovery~~a reduction in depreciation expense recognized in third quarter 2018 upon FERC approval of ~~lower operating~~the settlement in the Unit Power Sales Agreement proceeding, a reduction in income tax expense associated with the reduction in the federal income tax rate in 2018, and a reduction in recoverable decommissioning costs, primarily attributable to increased earnings on the decommissioning trust funds. This was

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partially offset by increases in other capacity costs. See Note 2 to the financial statements herein for a discussion of the Unit Power Sales Agreement settlement. See Note 3 to the financial statements in the Form 10-K for a discussion of the Tax Cut and Jobs Act.

The retail electric price variance is primarily due ~~to:~~to regulatory charges recorded in 2018 to reflect the effects of regulatory agreements to return the benefits of the lower income tax rate in 2018 to customers in Louisiana and New Orleans. The decrease was substantially offset by the following:

an increase in formula rate plan rates effective with the first billing cycle of January 2018 at Entergy Arkansas, as approved by the APSC;

an increase in energy efficiency revenues;

higher storm damage rider revenues at Entergy Mississippi; and

~~increases~~an increase in the distribution cost recovery factor rider rate in September 2017 at Entergy Texas, as approved by the PUCT.

The increase was partially offset by regulatory charges recorded in 2018 to reflect the effects of regulatory agreements to return the benefits of the lower income tax rate in 2018 to customers in Louisiana and New Orleans. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the regulatory proceedings discussed above.

The net wholesale revenue variance is primarily because of the regulatory lag experienced by certain Utility operating companies as a result of the change in the federal income tax rate in 2018 and its effect on wholesale rates. See Note 2 herein and in the Form 10-K for discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

The volume/weather variance is primarily due to an increase of ~~2,725~~4,576 GWh, or 5%, in billed electricity usage, including the effect of more favorable weather on residential and commercial sales and an increase in industrial usage. The increase in industrial usage is primarily ~~due to a~~driven by small industrials sales, as well as continued growth from new ~~customer in the primary metals industry.~~

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expansion customers.

Entergy Wholesale Commodities

Following is an analysis of the change in net revenue comparing the ~~six~~nine months ended ~~June~~September 30, 2018 to the ~~six~~nine months ended ~~June~~September 30, 2017:



	Amount
	(In Millions)
2017 net revenue		$~~744~~1,136
FitzPatrick reimbursement agreement	(98		)
Nuclear realized price changes	(1135		)
Nuclear volume	3521
Other	(1629		)
2018 net revenue		$~~654~~995

As shown in the table above, net revenue for Entergy Wholesale Commodities decreased by ~~$90~~$141 million in the ~~six~~nine months ended ~~June~~September 30, 2018 as compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to:

a decrease resulting from the reimbursement agreement with Exelon pursuant to which Exelon reimbursed Entergy in the first quarter 2017 for specified out-of-pocket costs associated with preparing for the refueling and operation of FitzPatrick that otherwise would have been avoided had Entergy shut down FitzPatrick in January 2017. Revenues received from Exelon under the reimbursement agreement were offset by other operation and maintenance expenses and taxes other than income taxes and had no effect on net income. See Note 14 to the financial statements in the Form 10-K for discussion of the sale of FitzPatrick and the reimbursement agreement with Exelon; and

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lower realized wholesale energy prices and the effect of rising forward power prices on electricity derivative instruments that are not designated as hedging instruments, partially offset by higher capacity prices.

The decrease was partially offset by higher volume in the Entergy Wholesale Commodities nuclear fleet resulting from fewer refueling outage days in the nine months ended September 30, 2018, partially offset by a larger exercise of resupply options in the ~~six~~nine months ended ~~June~~September 30, 2017 provided for in purchase power agreements where Entergy Wholesale Commodities may elect to supply power from another source when the plant is not running.

Following are key performance measures for Entergy Wholesale Commodities for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017:

2018 2017
Owned capacity (MW) 3,962 3,962
GWh billed 14,277 14,382

Entergy Wholesale Commodities Nuclear Fleet
Capacity factor 85% 71%
GWh billed 13,121 13,228
Average energy and capacity revenue per MWh $49.21 $53.79
Refueling outage days:
FitzPatrick — 42
Indian Point 2 33 —
Indian Point 3 — 66
Pilgrim — 43
Palisades — 27

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	2018	2017
Owned capacity (MW)	3,962	3,962
GWh billed	21,853	22,616

Entergy Wholesale Commodities Nuclear Fleet
Capacity factor	86%	79%
GWh billed	20,096	20,861
Average energy price ($/MWh)	$40.72	$42.46
Average capacity price ($/kW-month)	$7.01	$6.33
Refueling outage days:
FitzPatrick	—	42
Indian Point 2	33	—
Indian Point 3	—	66
Pilgrim	—	43
Palisades	—	27

Other Income Statement Items

Utility

Other operation and maintenance expenses increased from ~~$1,155~~$1,738 million for the ~~six~~nine months ended ~~June~~September 30, 2017 to ~~$1,217~~$1,852 million for the ~~six~~nine months ended ~~June~~September 30, 2018 primarily due to:

an increase of ~~$23~~$38 million in fossil-fueled generation expenses primarily due to an overall higher scope of work performed ~~during outages~~ in 2018 as compared to 2017;

an increase of ~~$13 million in nuclear generation expenses primarily due to~~ ~~a higher scope of work performed during plant outages in 2018 as compared to the same period in 2017 and~~ ~~higher nuclear labor costs, including contract labor, to position the nuclear fleet to meet its operational goals;~~

~~an increase of $13~~$27 million in energy efficiency costs;

an increase of $12 million in storm damage provisions, primarily at Entergy Mississippi. See Note 2 to the financial statements herein and in the Form 10-K for discussion of storm cost recovery; ~~and~~

an increase of $8$11 million in customer service costs primarily due to higher contract costs;

an increase of $10 million in transmission expenses primarily due to higher labor and contract costs to support industrial customers;

an increase of $10 million in information technology costs primarily due to higher software maintenance costs and higher labor costs, including contract labor;

an increase of $6 million in nuclear generation expenses primarily due to higher nuclear labor costs, including contract labor, to position the nuclear fleet to meet its operational goals and a higher scope of work performed during plant outages in 2018 as compared to the same period in 2017;

a $6 million loss in 2018 on the sale of fuel oil inventory per an agreement approved by the MPSC in June 2018 resulting from the stipulation related to the effects of the Tax Act. There is no effect on net income as the loss on the sale of fuel oil inventory is offset by a reduction in income tax expense; and

an increase of $6 million in vegetation maintenance costs.

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The increase was partially offset by higher nuclear insurance refunds of $15 million.

Taxes other than income taxes increased primarily due to increases in ad valorem taxes ~~local franchise taxes,~~ and payroll taxes. Ad valorem taxes increased primarily due to higher assessments. ~~Local franchise taxes~~

Other income increased primarily due to changes in decommissioning trust fund investment activity, including portfolio rebalancing of certain of the decommissioning trust funds in the third quarter 2018 and an increase in the allowance for equity funds used during construction due to higher ~~revenues~~construction work in progress in 2018, ~~as compared to 2017.~~

~~Depreciation and amortization expenses increased primarily due to additions to plant in service.~~which included the St. Charles Power Station project.

Entergy Wholesale Commodities

Other operation and maintenance expenses decreased from ~~$476~~$661 million for the ~~six~~nine months ended ~~June~~September 30, 2017 to ~~$391~~$599 million for the ~~six~~nine months ended ~~June~~September 30, 2018 primarily due to the absence of other operation and maintenance expenses from the FitzPatrick plant, which was sold to Exelon in March 2017. The decrease was partially offset by an increase of $17 million in severance and retention costs as a result of management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. See ~~Note 14 to~~“MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the ~~financial statements~~Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to reduce the ~~sale~~size of ~~FitzPatrick.~~the Entergy Wholesale Commodities’ merchant fleet.

The asset write-offs, impairments, and related charges variance is primarily due to impairment charges of ~~$142~~$297 million ($~~112~~235 million net-of-tax) in the ~~six~~nine months ended ~~June~~September 30, 2018 compared to impairment charges of ~~$405~~$422 million ($~~263~~274 million net-of-tax) in the ~~six~~nine months ended ~~June~~September 30, 2017. The impairment charges are due to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets being 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. The decrease in impairment charges in 2018 is primarily due to Palisades expenditures incurred after September 30, 2017, no longer being charged to expense as incurred but recorded as assets and depreciated or amortized, and the timing of nuclear refueling outage spending and nuclear fuel spending at the remaining impaired Entergy Wholesale Commodities nuclear ~~plants.~~plants, partially offset by an increase in impairment charges related to Pilgrim primarily resulting from the effects of an updated decommissioning cost study. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. See Note 14 to the financial statements herein for a discussion of asset retirement obligations. See Note 14 to the financial statements in the Form 10-K for a discussion of impairment of long-lived assets.

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The gain on sale of assets resulted from the sale in March 2017 of the 838 MW FitzPatrick plant to Exelon. Entergy sold the FitzPatrick plant for approximately $110 million, which included a $10 million non-refundable signing fee paid in August 2016, in addition to the assumption by Exelon of certain liabilities related to the FitzPatrick plant, resulting in a pre-tax gain of $16 million on the sale. See Note 14 to the financial statements in the Form 10-K for discussion of the sale of FitzPatrick.

Other income ~~decreased~~increased primarily due to ~~losses~~higher realized gains on the decommissioning trust fund investments in the ~~six~~nine months ended ~~June~~September 30, 2018 as compared to the ~~six~~nine months ended ~~June~~September 30, 2017, including ~~unrealized losses on equity investments, which, prior to 2018, were recorded to other comprehensive income. See Note 9 to~~ the ~~financial statements herein for discussion~~effect of ~~the implementation~~portfolio rebalancing in 2018.

Table of ~~ASU No. 2016-01 “Financial Instruments (Subtopic 825-10): Recognition~~Contents

Entergy Corporation and ~~Measurement of~~Subsidiaries

Management's Financial ~~Assets~~Discussion and ~~Financial Liabilities” effective January 1, 2018.~~Analysis

Other expenses decreased primarily due to the absence of decommissioning expense from the FitzPatrick plant after it was sold to Exelon in March 2017 and a reduction in deferred refueling outage amortization costs related to the impairments of the Indian Point 3, Indian Point 2, and Palisades plants and related assets. See Note 14 to the financial statements in the Form 10-K for discussion of the sale of FitzPatrick and impairments and related charges.

Income Taxes

The effective income tax rate was ~~(160%~~(128.4%) for the ~~six~~nine months ended ~~June~~September 30, 2018. The difference in the effective income tax rate for the ~~six~~nine months ended ~~June~~September 30, 2018 versus the federal statutory rate of 21% was primarily due to amortization of excess accumulated deferred income taxes, a restructuring of the investment holdings in one of the Entergy Wholesale Commodities’ nuclear plant decommissioning trusts for which additional tax basis is now recoverable, and an IRS audit settlement for the 2012-2013 tax returns. See Notes 2 and 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 10 to the financial statements herein for a discussion of the IRS audit ~~settlement.~~settlement and the restructuring.

The effective income tax rate was ~~(193.7%~~(10.8%) for the ~~six~~nine months ended ~~June~~September 30, 2017. The difference in the effective income tax rate for the ~~six~~nine months ended ~~June~~September 30, 2017 versus the federal statutory rate of 35% was primarily due to a change in the tax classification of legal entities that own Entergy Wholesale Commodities nuclear power plants, which resulted in both permanent and temporary differences under the income tax accounting standards and the re-determined tax basis of the FitzPatrick plant as a result of its sale on March 31, ~~2017.~~2017, partially offset by state income taxes. See Note 3 to the financial statements in the Form 10-K for further discussion of the change in tax classification and the tax benefit associated with the sale of FitzPatrick.

Income Tax Legislation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Income Tax Legislation” in the Form 10-K for a discussion of the Tax Cuts and Jobs Act enacted in December 2017.

See Note 2 to the financial statements herein and in the Form 10-K for discussion of proceedings commenced or other responses by Entergy’s regulators to the Tax Act.

Entergy Wholesale Commodities Exit from the Merchant Power Business

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” in the Form 10-K for a discussion of management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. Following are updates to that discussion.

Shutdown and Planned Sale of Vermont Yankee

As discussed in the Form 10-K, in December 2014 the Vermont Yankee plant ceased power production and entered its decommissioning phase, and in November 2016, Entergy entered into an agreement to sell 100% of the

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membership interests in Entergy Nuclear Vermont Yankee, LLC to a subsidiary of NorthStar. In March 2018, Entergy and NorthStar entered into a settlement agreement and a Memorandum of Understanding with State of Vermont agencies and other interested parties that set forth the terms on which the agencies and parties support the Vermont Public Utility Commission’s approval of the transaction. The agreements provide additional financial assurance for decommissioning, spent fuel management and site restoration, and detail the site restoration standards that will apply to protect the environment and the health and safety of workers and the public. The provisions of the agreements will become effective upon approval of the transaction by the Vermont Public Utility Commission consistent with the agreements’ terms, the NRC’s approval of the license transfer application, and the closing of the transaction. In October 2018 the

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NRC issued an order approving the application to transfer Vermont Yankee’s license to NorthStar for decommissioning. The Vermont Public Utility Commission ~~and the NRC are~~is expected to issue ~~their decisions~~its decision in the ~~third or~~ fourth quarter of 2018.

Entergy Nuclear Vermont Yankee has an outstanding credit facility with borrowing capacity of $145 million to pay for dry fuel storage costs. This credit facility is guaranteed by Entergy Corporation. At or before closing, a subsidiary of Entergy will assume the obligations under the existing credit facility or enter into a new credit facility, and Entergy will guarantee the credit facility. At the closing of the sale transaction, NorthStar will pay $1,000 for the membership interests in Entergy Nuclear Vermont Yankee, and NorthStar will cause Entergy Nuclear Vermont Yankee to issue a promissory note to an Entergy affiliate. The amount of the promissory note issued will be equal to the amount drawn under the credit facility or the amount drawn under the new credit facility, plus borrowing fees and costs incurred by Entergy in connection with such facility. The principal amount drawn under the outstanding credit facility was ~~$108~~$132 million as of ~~June~~September 30, 2018. The transaction is expected to result in a loss based on the difference between Entergy’s net investment in Entergy Nuclear Vermont Yankee and the sale price plus any agreed adjustments. As of ~~June~~September 30, 2018, ~~the~~Entergy’s adjusted net investment in Entergy Nuclear Vermont Yankee was ~~$245~~$266 million. The primary variables in the ultimate loss are the values of the nuclear decommissioning trusts and the asset retirement obligations at closing, financial results from the plant until the closing, and any changes in Entergy’s investment in Entergy Nuclear Vermont Yankee before closing.

Planned Sales of Pilgrim and Palisades

On July 30, 2018, Entergy entered into purchase and sale agreements with Holtec International to sell to a Holtec subsidiary (i) 100% of the equity interests in Entergy Nuclear Generation Company, the owner of Pilgrim, and (ii) 100% of the equity interests in Entergy Nuclear Palisades, LLC, the owner of Palisades and the Big Rock Point Site. The sales of Entergy Nuclear Generation Company and Entergy Nuclear Palisades will include the transfer of each entity’s nuclear decommissioning trust and obligation for spent fuel management and plant decommissioning. At the closing of each sale transaction, the Holtec subsidiary will pay $1,000 each (subject to adjustment for net liabilities and other amounts) for the equity interests in Entergy Nuclear Generation Company and Entergy Nuclear Palisades.

The Pilgrim transaction is subject to certain closing conditions, including: the permanent shutdown of Pilgrim and the transfer of all nuclear fuel from the reactor vessel to the spent nuclear fuel pool; NRC approval for the transfer of the operating and the independent spent fuel storage installation licenses; FERC approval for the change in control of the switchyard; receipt of a favorable private letter ruling from the IRS; the market value of the nuclear decommissioning trust for Pilgrim, less the hypothetical income tax on the aggregate unrealized gain of such fund assets at closing, ~~equals~~equaling or ~~exceeds~~exceeding a specified minimum amount; and, the Palisades purchase and sale agreement ~~has~~ not having been terminated due to a breach by Holtec or its subsidiary.

The Palisades transaction is subject to certain closing conditions, including: the permanent shutdown of Palisades and the transfer of all nuclear fuel from the reactor vessel to the spent nuclear fuel pool; NRC regulatory approval for the transfer of the Palisades and Big Rock Point operating and independent spent fuel storage installation licenses; receipt of a favorable private letter ruling from the IRS; the market value of the nuclear decommissioning trust for Palisades, less the hypothetical income tax on the aggregate unrealized gain of such fund assets at closing, ~~equals~~equaling or ~~exceeds~~exceeding a specified minimum amount; and, the Pilgrim transaction ~~has~~having closed.

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Subject to the above conditions, the Pilgrim transaction is expected to close by the end of 2019 and the Palisades transaction is expected to close by the end of 2022. Each transaction is expected to result in a loss based on the difference between Entergy’s net investment in each subsidiary and the sale price plus any agreed adjustments. As of ~~June~~September 30, 2018, ~~the~~Entergy’s adjusted net investment in Entergy Nuclear Generation Company was ~~$557~~$456 million and ~~the~~Entergy’s adjusted net investment in Entergy Nuclear Palisades was ~~$131~~$210 million. The primary variables in the ultimate loss are the values of the nuclear decommissioning trusts and the asset retirement obligations at closing, financial results from plant operations until the closing, and the level of any deferred tax balances at closing.

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Costs Associated with Entergy Wholesale Commodities Strategic Transactions

Entergy 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 $155 million in 2018, of which ~~$60~~$103 million has been incurred as of ~~June~~September 30, 2018, and a total of approximately $215 million from 2019 through mid-2022. In addition, Entergy Wholesale Commodities incurred impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets of ~~$69~~$155 million for the three months ended ~~June~~September 30, 2018 and ~~$142~~$297 million for the ~~six~~nine months ended ~~June~~September 30, 2018. These costs were charged to expense as incurred as a result of the impaired value of certain 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. Entergy expects to continue to incur costs associated with nuclear fuel-related spending and expenditures for capital assets and, except for Palisades, expects to continue to charge these costs to expense as incurred because Entergy expects the value of the plants to continue to be impaired.

Entergy Wholesale Commodities Authorizations to Operate Indian Point

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Authorizations to Operate Indian Point” in the Form 10-K for a discussion of the NRC operating licensing proceedings for Indian Point 2 and Indian Point 3 and the settlement reached with New York State in January 2017. Following are updates to that discussion.

In April 2018 the NRC issued a supplement to the final supplemental environmental impact statement, and in August 2018 the NRC issued a supplemental safety evaluation report. The supplements update the environmental record and safety record related to the Indian Point license renewal. ~~The~~In September 2018 the NRC ~~is expected to issue its decision in the~~issued renewed operating licenses for Indian Point 2 through April 2024 and for Indian Point 3 ~~license renewal proceedings in fourth quarter 2018.~~through April 2025.

As discussed in the Form 10-K, ~~operations~~in January 2017, Entergy reached a settlement with New York State, several State agencies, and Riverkeeper, Inc. under which Indian Point 2 and Indian Point 3 will cease commercial operation by April 30, 2020 and April 30, 2021, respectively. Operations may be extended up to four additional years for each unit by mutual agreement of Entergy and New York State based on an exigent reliability need for Indian Point generation. In accordance with the FERC-approved tariff of the New York Independent System Operator (NYISO), Entergy submitted to the NYISO a notice of generator deactivation based on the dates in the ~~settlement (no later than April 30, 2020 for Indian Point 2 and April 30, 2021 for Indian Point 3).~~settlement. In December 2017 the NYISO issued a report stating there will not be a system reliability need following the deactivation of Indian Point. In April 2018 the NYISO issued a determination that the retirement of Indian Point was economically justified and, therefore, did not raise competition concerns.

Liquidity and Capital Resources

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy’s capital structure, capital expenditure plans and other uses of capital, and sources of capital. Following are updates to that discussion.

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Capital Structure

Entergy’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio for Entergy as of ~~June~~September 30, 2018 is primarily due to the net issuance of debt in 2018.


	June 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Debt to capital	68.5	%	67.1	%	68.2	%	67.1	%
Effect of excluding securitization bonds	(0.6	%)	(0.8	%)	(0.5	%)	(0.8	%)
Debt to capital, excluding securitization bonds (a)	67.9	%	66.3	%	67.7	%	66.3	%
Effect of subtracting cash	(1.0	%)	(1.1	%)	(1.3	%)	(1.1	%)
Net debt to net capital, excluding securitization bonds (a)	66.9	%	65.2	%	66.4	%	65.2	%


(a)	Calculation excludes the Arkansas, Louisiana, New Orleans, and Texas securitization bonds, which are non-recourse to Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas, respectively.

Net debt consists of debt less cash and cash equivalents. Debt consists of notes payable and commercial paper, capital lease obligations, and long-term debt, including the currently maturing portion. Capital consists of debt, common shareholders’ equity, and subsidiaries’ preferred stock without sinking fund. Net capital consists of capital less cash and cash equivalents. Entergy uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy’s financial condition because the securitization bonds are non-recourse to Entergy, as more fully described in Note 5 to the financial statements in the Form 10-K. Entergy also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy’s financial condition because net debt indicates Entergy’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in ~~August 2022.~~September 2023. 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 ~~six~~nine months ended ~~June~~September 30, 2018 was ~~3.34%~~3.46% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of ~~June~~September 30, 2018:


Capacity	Borrowings	Letters of Credit	Capacity Available	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$390	$6	$3,104	$630	$6	$2,864

A covenant in Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. The calculation of this debt ratio under Entergy Corporation’s credit facility is different than the calculation of the debt to capital ratio above. One such difference is that it excludes the effects, among other things, of certain impairments related to the Entergy Wholesale Commodities nuclear generation assets. Entergy is currently in compliance with the covenant and expects to remain in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy 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’s maturity date may occur. See Note 4 to the financial statements herein for additional discussion of the Entergy Corporation credit facility and discussion of the Registrant Subsidiaries’ credit facilities.

Entergy Nuclear Vermont Yankee has a credit facility guaranteed by Entergy Corporation with a borrowing capacity of $145 million that expires in November 2020. As of ~~June~~September 30, 2018, ~~$108~~$132 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the ~~six~~nine months ended ~~June 30, 2018 was~~September

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~~3.26%~~30, 2018 was 3.37% on the drawn portion of the facility. See Note 4 to the financial statements herein for additional discussion of the Vermont Yankee facility.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion. As of ~~June~~September 30, 2018, Entergy Corporation had approximately ~~$1,945~~$1,947 million of commercial paper outstanding. The weighted-average interest rate for the ~~six~~nine months ended ~~June~~September 30, 2018 was ~~2.31%~~2.42%.

Equity Forward Sale Agreements

In June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with several counterparties. Settlement of the forward sale agreements is expected to occur on or prior to June 7, 2019. See Note 3 to the financial statements herein for discussion of the equity forwards.

Capital Expenditure Plans and Other Uses of Capital

See the table and discussion in the Form 10-K under “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources - Capital Expenditure Plans and Other Uses of Capital,” that sets forth the amounts of planned construction and other capital investments by operating segment for 2018 through 2020. Following are updates to the discussion.

Preliminary Capital Investment Plan Estimate for 2019-2021

Entergy is developing its capital investment plan for 2019 through 2021 and currently anticipates that the Utility will make approximately $11.1 billion in capital investments during that period and that Entergy Wholesale Commodities will make approximately $0.2 billion in capital investments, not including nuclear fuel, during that period. The preliminary Utility estimate includes amounts associated with specific investments such as the New Orleans Power Station, the Washington Parish Energy Center, and the Choctaw Generating Station, each discussed below, the Lake Charles Power Station, the St. Charles Power Station, and the Montgomery County Power Station; transmission projects to enhance reliability, reduce congestion, and enable economic growth; distribution spending to enhance reliability and improve service to customers, including advanced meters and related investments; resource planning, including potential generation projects; system improvements; investments in the nuclear fleet; software and security; and other investments. The preliminary Entergy Wholesale Commodities estimate includes amounts associated with specific investments, such as the investments in the nuclear fleet, component replacement, software and security, and dry cask storage. Estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of business restructuring, regulatory constraints and requirements, environmental regulations, business opportunities, market volatility, economic trends, changes in project plans, and the ability to access capital.

New Orleans Power Station

As discussed in the Form 10-K, in June 2016, Entergy New Orleans filed an application with the City Council seeking a public interest determination and authorization to construct the New Orleans Power Station, a 226 MW advanced combustion turbine in New Orleans, Louisiana, at the site of the existing Michoud generating facility. In July 2017, Entergy New Orleans submitted a supplemental and amending application to the City Council seeking approval to construct either the originally proposed 226 MW advanced combustion turbine, or alternatively, a 128 MW unit composed of natural gas-fired reciprocating engines and a related cost recovery plan. In March 2018 the City Council adopted a resolution approving construction of the 128 MW unit. The targeted commercial operation date is ~~January~~Spring 2020, subject to receipt of all necessary ~~permits.~~permits by the end of November 2018. In April 2018 intervenors opposing the construction of the New Orleans Power Station filed with the City Council a request for rehearing, which was subsequently denied, and a petition for judicial review of the City Council’s decision, and also filed a lawsuit challenging the City Council’s approval based on Louisiana’s open meeting law. In May 2018 the City Council announced that it would initiate an investigation into allegations that Entergy New Orleans, Entergy, or some other

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entity paid or participated in paying certain attendees and speakers in support of the New Orleans Power Station to attend or speak at certain meetings organized by the City Council. In June 2018, Entergy New Orleans produced documents in response to a City Council resolution relating to this investigation. The City Council issued a request for qualifications for an investigator and in June 2018 selected two investigators. In October 2018 the investigators for the City Council released their report, concluding that individuals were paid to attend and/or speak in support of the New Orleans Power Station and isthat Entergy New Orleans “knew or should have known that such conduct occurred or reasonably might occur.” The City Council held a special meeting on October 31, 2018 to allow the investigators to present the report and for the City Council to consider next steps. At that meeting, the City Council issued a resolution requiring Entergy New Orleans to show cause why it should not be fined $5 million as a result of the findings in the ~~process~~report. A response to the resolution is due within 30 days from issuance of ~~contracting~~the certified resolution. Entergy New Orleans disagrees with ~~them~~certain characterizations and omissions of fact in the report and submitted its response to ~~conduct~~ the ~~investigation.~~City Council.

Washington Parish Energy Center

As discussed in the Form 10-K, in April 2017, Entergy Louisiana signed an agreement with a subsidiary of Calpine Corporation for the construction and purchase of a peaking plant. In May 2017, Entergy Louisiana filed an application with the LPSC seeking certification of the plant. In April 2018 the parties reached a settlement recommending certification and cost recovery through the additional capacity mechanism of the formula rate plan, consistent with prior LPSC precedent with respect to the certification and recovery of plants previously acquired by Entergy Louisiana. The LPSC issued an order approving the settlement in May 2018.

Choctaw Generating Station

~~Table~~ In August 2018, Entergy Mississippi announced that it signed an asset purchase agreement to acquire from a subsidiary of ~~Contents~~

GenOn Energy Inc. the Choctaw Generating Station, an 810 MW natural gas fired combined-cycle turbine plant located near French Camp, Mississippi. The purchase price is expected to be approximately $314 million. Entergy ~~Corporation~~Mississippi also expects to invest in various plant upgrades at the facility after closing and ~~Subsidiaries~~

~~Management's Financial Discussion~~expects the total cost of the acquisition to be approximately $401 million. The purchase is contingent upon, among other things, obtaining necessary approvals, including full cost recovery, from applicable federal and ~~Analysis~~

state regulatory and permitting agencies. These include regulatory approvals from the MPSC and the FERC, as well as clearance under the Hart-Scott-Rodino Antitrust Improvements Act. In October 2018, Entergy Mississippi filed an application with the MPSC seeking approval of the acquisition and cost recovery. In a separate filing in October 2018, Entergy Mississippi proposed revisions to its formula rate plan that would provide for a mechanism, the interim capacity rate adjustment mechanism, in the formula rate plan to recover the non-fuel related costs of additional owned capacity acquired by Entergy Mississippi, including the non-fuel annual ownership costs of the Choctaw Generating Station, as well as to allow similar cost recovery treatment for other future capacity additions approved by the MPSC. Closing is expected to occur by the end of 2019.

Dividends

Declarations of dividends on Entergy’s common stock are made at the discretion of the Board. Among other things, the Board evaluates the level of Entergy’s common stock dividends based upon earnings per share from the Utility operating segment and the Parent and Other portion of the business, financial strength, and future investment opportunities. At its ~~July~~October 2018 meeting, the Board declared a dividend of ~~$0.89~~$0.91 per share, ~~which is~~an increase from the ~~same~~previous $0.89 quarterly dividend per share that Entergy has paid since the fourth quarter 2017.

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Cash Flow Activity

As shown in Entergy’s Consolidated Statements of Cash Flows, cash flows for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017 were as follows:


	2018			2017			2018			2017
	(In Millions)						(In Millions)
Cash and cash equivalents at beginning of period		$781			$1,188			$781			$1,188

Cash flow provided by (used in):
Operating activities	1,080			820			1,860			1,713
Investing activities	(1,929		)	(1,770		)	(3,000		)	(2,828		)
Financing activities	881			697			1,347			473
Net increase (decrease) in cash and cash equivalents	32			(253		)	207			(642		)

Cash and cash equivalents at end of period		$813			$935			$988			$546

Operating Activities

Net cash flow provided by operating activities increased by ~~$260~~$147 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to:

a decrease of ~~$126~~$130 million in spending on nuclear refueling outages in 2018 as compared to the same period in 2017;

severance and retention payments of $92 million in 2017. See Note 7 to the financial statements herein for a discussion of severance and retention costs in connection with management’s strategy to manage and reduce the risk of the Entergy Wholesale Commodities business;

a refund to customers in January 2017 of approximately $71 million as a result of the settlement approved by the LPSC related to the Waterford 3 replacement steam generator project. See Note 2 to the financial statements in the Form 10-K for discussion of the settlement and refund;

the effect of favorable weather on billed Utility sales in 2018; and

~~a decrease~~an increase due to the timing of ~~$16 million~~recovery of fuel and purchased power costs in ~~pension contributions~~ 2018 as compared to the same period in 2017. See ~~MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - “Critical Accounting Estimates~~”Note 2 to the financial statements in the Form 10-K ~~and Note 6 to the financial statements herein~~ for a discussion of ~~qualified pension~~fuel and ~~other postretirement benefits funding.~~

purchased power cost recovery.

The increase was partially offset by:

lower Entergy Wholesale Commodities net revenue in 2018 as compared to the same period in 2017 (except for the revenues resulting from the FitzPatrick reimbursement agreement with Exelon), as discussed above. See Note 14 to the financial statements in the Form 10-K for discussion of the reimbursement agreement;

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the return of unprotected excess accumulated deferred income taxes to Utility customers. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of the regulatory activity regarding the Tax Cuts and Jobs Act;

an increase of ~~$28~~$50 million in interest paid in 2018 as compared to the same period in 2017 resulting from an increase in interest expense;

income tax payments of ~~$14~~$18 million in 2018 compared to income tax refunds of ~~$15~~$12 million in 2017. Entergy made income tax payments in 2018 for estimated federal income taxes. Entergy received income tax refunds in 2017 resulting from the carryback of net operating losses; and

proceeds of $23 million received in 2017 from the DOE resulting from litigation regarding spent nuclear fuel storage costs that were previously expensed. See Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation.

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Investing Activities

Net cash flow used in investing activities increased ~~$159~~$172 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to:

an increase of ~~$166~~$261 million in construction expenditures, primarily in the Utility business. The increase in construction expenditures in the Utility business is primarily due to an increase of ~~$123~~$183 million in fossil-fueled generation construction expenditures primarily due to higher spending in 2018 on self-build projects in the ~~Lake Charles Power Station project~~Utility business and an increase of ~~$39~~$62 million in nuclear construction expenditures primarily due to a higher scope of work performed onduring the Grand Gulf outage ~~projects~~ in 2018;

proceeds of $100 million from the sale in March 2017 of the FitzPatrick plant to Exelon. See Note 14 to the financial statements in the Form 10-K for a discussion of the sale of FitzPatrick; and

proceeds of $25 million received in 2017 from the DOE resulting from litigation regarding spent nuclear fuel storage costs that were previously capitalized. See Note 8 to the financial statements in the Form 10-K for discussion of the DOE litigation.

The increase was partially offset by by:

$113 million in funds held on deposit in 2017 for principal and interest payments that were due October 1, 2017;

changes in the decommissioning trust funds, including portfolio rebalancing of certain decommissioning trust funds in the third quarter 2018; and

a decrease of ~~$119~~$55 million in nuclear fuel purchases due to variations from year to year in the timing and pricing of fuel reload requirements, material and services deliveries, and the timing of cash payments during the nuclear fuel cycle.

Financing Activities

Net cash flow provided by financing activities increased ~~$184~~$874 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to long-term debt activity providing approximately ~~$790~~$1,422 million of cash in 2018 compared to ~~providing~~using approximately ~~$170 million~~$309 thousand in 2017. Borrowings and repayments of borrowings on Entergy’s long-term credit facility are included in long-term debt activity. The increase was partially offset by a decrease of ~~$324~~$448 million in net issuances of commercial paper in 2018 compared to the same period in 2017 and a net decrease of ~~$104~~$121 million in 2018 in short-term borrowings by the nuclear fuel company variable interest entities. For the details of Entergy’s commercial paper program, the nuclear fuel company variable interest entities’ short-term borrowings, and long-term debt, see Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K.

Rate, Cost-recovery, and Other Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Rate, Cost-recovery, and Other Regulation” in the Form 10-K for discussions of rate regulation, federal regulation, and related regulatory proceedings.

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State and Local Rate Regulation and Fuel-Cost Recovery

See Note 2 to the financial statements herein for updates to the discussion in the Form 10-K regarding these proceedings.

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Federal Regulation

See Note 2 to the financial statements herein for updates to the discussion in the Form 10-K regarding federal regulatory proceedings.

Market and Credit Risk Sensitive Instruments

Commodity Price Risk

Power Generation

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 in the day ahead or spot markets. Entergy Wholesale Commodities also sells unforced capacity, which allows load-serving entities to meet specified reserve and related requirements placed on them by the ISOs in their respective areas. Entergy Wholesale Commodities’ forward physical power contracts consist of contracts to sell energy only, contracts to sell capacity only, and bundled contracts in which it sells both capacity and energy. While the terminology and payment mechanics vary in these contracts, each of these types of contracts requires Entergy Wholesale Commodities to deliver MWh of energy, make capacity available, or both. In addition to its forward physical power contracts, Entergy Wholesale Commodities may also ~~uses~~use a combination of financial contracts, including swaps, collars, and options, to manage forward commodity price risk. Certain hedge volumes have price downside and upside relative to market price movement. The contracted minimum, expected value, and sensitivities are provided in the table below to show potential variations. The sensitivities may not reflect the total maximum upside potential from higher market prices. The information contained in the following table represents projections at a point in time and will vary over time based on numerous factors, such as future market prices, contracting activities, and generation. Following is a summary of Entergy Wholesale Commodities’ current forward capacity and generation contracts as well as total revenue projections based on market prices as of ~~June~~September 30, 2018 (2018 represents the remainder of the year):

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Entergy Wholesale Commodities Nuclear Portfolio


	2018	2019	2020	2021	2022	2018	2019	2020	2021	2022
Energy
Percent of planned generation under contract (a):
Unit-contingent (b)	98%	94%	81%	84%	67%	98%	95%	86%	87%	66%
Firm LD (c)	9%	—%	—%	—%	—%	10%	—%	—%	—%	—%
Offsetting positions (d)	(9%)	—%	—%	—%	—%	(10%)	—%	—%	—%	—%
Total	98%	94%	81%	84%	67%	98%	95%	86%	87%	66%
Planned generation (TWh) (e) (f)	14.1	25.5	17.8	9.7	2.8	6.7	25.6	17.7	9.6	2.8
Average revenue per MWh on contracted volumes:
Expected based on market prices as of June 30, 2018	$33.1	$40.2	$41.7	$57.9	$58.8
Expected based on market prices as of September 30, 2018						$33.6	$40.3	$42.9	$57.3	$58.8

Capacity				��
Percent of capacity sold forward (g):
Bundled capacity and energy contracts (h)	22%	25%	37%	68%	97%	22%	26%	36%	68%	97%
Capacity contracts (i)	45%	16%	—%	—%	—%	42%	22%	3%	—%	—%
Total	67%	41%	37%	68%	97%	64%	48%	39%	68%	97%
Planned net MW in operation (average) (f)	3,568	3,167	2,195	1,158	338	3,568	3,167	2,195	1,158	338
Average revenue under contract per kW per month (applies to capacity contracts only)	$8.8	$7.7	$—	$—	$—	$8.0	$7.2	$1.8	$—	$—

Total Energy and Capacity Revenues (j)
Expected sold and market total revenue per MWh	$45.8	$46.5	$47.3	$56.3	$47.6	$44.1	$46.3	$46.9	$55.3	$47.1
Sensitivity: -/+ $10 per MWh market price change	$45.8	$45.9-$47.0	$45.8-$48.9	$54.6-$57.9	$44.3-$50.9	$44.0-$44.3	$45.8-$46.8	$45.9-$47.9	$54.0-$56.7	$43.3-$50.9


(a)	Percent of planned generation output sold or purchased forward under contracts, forward physical contracts, forward financial contracts, or options that mitigate price uncertainty that may require regulatory approval or approval of transmission rights. Positions that are not classified as hedges are netted in the planned generation under contract.

(b)

Transaction under which power is supplied from a specific generation asset; if the asset is not operating, the seller is generally not liable to the buyer for any damages. Certain unit-contingent sales include a guarantee of availability. Availability guarantees provide for the payment to the power purchaser of contract damages, if incurred, in the event the seller fails to deliver power as a result of the failure of the specified generation unit to generate power at or above a specified availability threshold. All of Entergy’s outstanding guarantees of availability provide for dollar limits on Entergy’s maximum liability under such guarantees.

(c)

Transaction that requires receipt or delivery of energy at a specified delivery point (usually at a market hub not associated with a specific asset) or settles financially on notional quantities; if a party fails to deliver or receive energy, the defaulting party must compensate the other party as specified in the contract, a portion of which may be capped through the use of risk management products. This also includes option transactions that may expire without being exercised.


(d)	Transactions for the purchase of energy, generally to offset a Firm LD transaction.


(e)	Amount of output expected to be generated by Entergy Wholesale Commodities resources considering plant operating characteristics, outage schedules, and expected market conditions that affect dispatch.

(f)

Assumes the planned shutdown of Pilgrim on May 31, 2019, planned shutdown of Indian Point 2 on April 30, 2020, planned shutdown of Indian Point 3 on April 30, 2021, and planned shutdown of Palisades on May 31, 2022. ~~Assumes NRC license renewals for two units, as follows (with current license expirations in parentheses):~~For a discussion regarding the planned shutdown of the Pilgrim, Indian Point 2, Indian Point 3, and

1719

Table of Contents

Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Indian Point 2 (September 2013 and now operating under its period of extended operations while its application is pending) and Indian Point 3 (December 2015 and now operating under its period of extended operations while its application is pending). For a discussion regarding the planned shutdown of the Pilgrim, Indian Point 2, Indian Point 3, and Palisades plants, see “Entergy Wholesale Commodities Exit from the Merchant Power Business” ~~in the Form 10-K. For a discussion regarding the license renewals for Indian Point 2 and Indian Point 3, see “Entergy Wholesale Commodities Authorizations to Operate Indian Point” herein and~~ in the Form 10-K.


(g)	Percent of planned qualified capacity sold to mitigate price uncertainty under physical or financial transactions.


(h)	A contract for the sale of installed capacity and related energy, priced per megawatt-hour sold.


(i)	A contract for the sale of an installed capacity product in a regional market.


(j)	Includes assumptions on converting a portion of the portfolio to contracted with fixed price cost or discount and excludes non-cash revenue from the amortization of the Palisades below-market purchased power agreement, mark-to-market activity, and service revenues.

Entergy estimates that a positive $10 per MWh change in the annual average energy price in the markets in which the Entergy Wholesale Commodities nuclear business sells power, based on ~~June~~September 30, 2018 market conditions, planned generation volumes, and hedged positions, would have a corresponding effect on pre-tax income of ~~$34 thousand~~($1) million for the remainder of 2018. As of ~~June~~September 30, 2017, a positive $10 per MWh change would have had a corresponding effect on pre-tax income of ~~$19~~$9 million for the remainder of 2017. A negative $10 per MWh change in the annual average energy price in the markets based on ~~June~~September 30, 2018 market conditions, planned generation volumes, and hedged positions, would have a corresponding effect on pre-tax income of ~~($34) thousand~~$1 million for the remainder of 2018. As of ~~June~~September 30, 2017, a negative $10 per MWh change would have had a corresponding effect on pre-tax income of ($~~17)~~9) million for the remainder of 2017.

Some 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 under the agreements. The Entergy subsidiary is required to provide credit support based upon the difference between the current market prices and contracted power prices in the regions where Entergy Wholesale Commodities sells power. The primary form of credit support to satisfy these requirements is an Entergy Corporation guaranty. Cash and letters of credit are also acceptable forms of credit support. At ~~June~~September 30, 2018, based on power prices at that time, Entergy had liquidity exposure of ~~$117~~$131 million under the guarantees in place supporting Entergy Wholesale Commodities transactions and ~~$17~~$42 million of posted cash collateral. In the event of a decrease in Entergy Corporation’s credit rating to below investment grade, based on power prices as of ~~June~~September 30, 2018, Entergy would have been required to provide approximately ~~$48~~$78 million of additional cash or letters of credit under some of the agreements. As of ~~June~~September 30, 2018, the liquidity exposure associated with Entergy Wholesale Commodities assurance requirements, including return of previously posted collateral from counterparties, would increase by ~~$339~~$307 million for a $1 per MMBtu increase in gas prices in both the short- and long-term markets.

As of ~~June~~September 30, 2018, substantially all of the credit exposure associated with the planned energy output under contract for Entergy Wholesale Commodities nuclear plants through 2022 is with counterparties or their guarantors that have public investment grade credit ratings.

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of nuclear matters. The following are updates to that discussion.

ANO

~~Table of Contents~~

~~Entergy Corporation and Subsidiaries~~

~~Management's Financial Discussion and Analysis~~

the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. This action followed NRC inspections to review ANO 1’s and ANO 2’s performance in addressing issues that had previously resulted in classification in Column 4.

Table of Contents

Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Grand Gulf

As discussed in the Form 10-K, in November 2016 the NRC placed Grand Gulf in the “regulatory response column,” or Column 2, of its Reactor Oversight Process Action Matrix. In August 2018 the NRC moved Grand Gulf into Column 1 of the NRC’s Reactor Oversight Process Action Matrix. This action followed NRC inspections to review Grand Gulf’s performance in addressing issues that had previously resulted in classification in Column 2. Based on performance indicator data for the third quarter 2018, Entergy expects that the NRC will announce that Grand Gulf has moved back to Column 2. In August 2018 operators safely performed a reduction in power to address an operational issue with a plant system. As a result of the power reduction, the threshold for one of the NRC’s performance indicators was exceeded, which results in a Column 2 designation under the NRC’s Reactor Oversight Process Action Matrix at least until new performance indicator data is reported in the first quarter 2019.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy’s accounting for nuclear decommissioning costs, utility regulatory accounting, unbilled revenue, impairment of long-lived assets and trust fund investments, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See Note 1 to the financial statements in the Form 10-K for discussion of new accounting pronouncements. The following ~~is an update~~are updates to that discussion.

In February 2016 the FASB issued ASU No. 2016-02, “Leases (Topic 842).” The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. In January 2018 the FASB issued ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” providing entities the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard. In July 2018 the FASB issued ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements,” which is intended to simplify the transition requirements giving entities the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period presented and provides a practical expedient for the separation of lease and nonlease components for lessors. Entergy plans to adopt ASU 2016-02 along with the practical expedients provided by ASU 2018-01 and 2018-11 when they become effective for Entergy in the first quarter 2019. Entergy ~~expects~~does not expect that ASU 2016-02 will materially affect its results of operations, financial position, or cash flows but it will significantly expand the level of lease related disclosure.

In September 2018 the FASB issued ASU No. 2018-15, “Intangibles - Goodwill and Other - Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service.” The ASU requires entities to capitalize implementation costs associated with cloud computing arrangements classified as hosting arrangements and amortize those costs over the contract term. These costs are required to be capitalized in the same line as prepayments of the costs, and subsequently amortized in the same lines as the hosting service element of the arrangement. ASU 2018-15 is effective for Entergy for the first quarter 2020. Entergy does not expect to early adopt the standard. Entergy expects that it will elect to adopt ASU 2018-15 on a prospective basis, which will affect its statement of financial position by ~~increasing~~presenting implementation costs for hosting arrangements as prepayments, and net income by amortizing those costs as operation and maintenance expense over the ~~assets and liabilities recorded relating to its operating leases.~~contract term of the arrangement. Entergy is evaluating ASU ~~2016-02~~2018-15 for other effects on its results of operations, financial position, or cash ~~flows, and financial statement disclosures, as well as the potential to elect various other practical expedients permitted by the standards.~~flows.

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2018 and 2017
(Unaudited)

Three Months Ended Six Months Ended
2018 2017 2018 2017
(In Thousands, Except Share Data)
OPERATING REVENUES
Electric
$2,330,225

$2,271,220

$4,578,486

$4,262,960
Natural gas 29,943
30,075
86,638
73,426
Competitive businesses 308,602
317,255
727,526
870,622
TOTAL 2,668,770
2,618,550
5,392,650
5,207,008

OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale 465,802
395,947
909,098
813,513
Purchased power 417,034
416,497
813,058
774,264
Nuclear refueling outage expenses 35,360
38,288
78,120
80,853
Other operation and maintenance 840,103
794,967
1,623,687
1,641,825
Asset write-offs, impairments, and related charges 68,943
193,571
141,867
405,362
Decommissioning 97,605
100,296
192,005
214,669
Taxes other than income taxes 158,547
153,264
323,765
309,616
Depreciation and amortization 350,485
350,328
697,471
697,593
Other regulatory charges (credits) 143,294
6,553
186,319
(78,749 )
TOTAL 2,577,173
2,449,711
4,965,390
4,858,946

Gain on sale of assets —
—
—
16,270

OPERATING INCOME 91,597
168,839
427,260
364,332

OTHER INCOME
Allowance for equity funds used during construction 31,670
22,376
60,014
41,384
Interest and investment income 71,134
80,097
88,005
136,646
Miscellaneous - net (48,491 ) (32,202 ) (79,849 ) (47,391 )
TOTAL 54,313
70,271
68,170
130,639

INTEREST EXPENSE
Interest expense 192,314
173,377
375,237
344,466
Allowance for borrowed funds used during construction (14,668 ) (10,523 ) (27,933 ) (19,565 )
TOTAL 177,646
162,854
347,304
324,901

INCOME (LOSS) BEFORE INCOME TAXES (31,736 ) 76,256
148,126
170,070

Income taxes (280,596 ) (337,112 ) (236,933 ) (329,350 )

CONSOLIDATED NET INCOME 248,860
413,368
385,059
499,420

Preferred dividend requirements of subsidiaries 3,439
3,446
6,878
6,892

NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
$245,421

$409,922

$378,181

$492,528

Earnings per average common share:
Basic
$1.36

$2.28

$2.09

$2.75
Diluted
$1.34

$2.27

$2.08

$2.74
Dividends declared per common share
$0.89

$0.87

$1.78

$1.74

Basic average number of common shares outstanding 180,823,203
179,475,346
180,765,708
179,405,592
Diluted average number of common shares outstanding 182,982,630
180,234,694
182,208,328
180,032,233

See Notes to Financial Statements.

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Six Months Ended June 30, 2018 and 2017
(Unaudited)

Three Months Ended Six Months Ended
2018 2017 2018 2017
(In Thousands)

Net Income
$248,860

$413,368

$385,059

$499,420

Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss) (net of tax expense (benefit) of ($17,312), $10,684, $8,037, and $10,325) (65,068 ) 19,949
30,359
19,421
Pension and other postretirement liabilities (net of tax expense of $4,225, $5,839, $8,793, and $12,216) 15,565
10,916
32,139
19,548
Net unrealized investment gain (loss) (net of tax expense (benefit) of ($2,842), $2,870, $2,533, and $42,164) (2,641 ) 11,696
(35,497 ) 49,523
Foreign currency translation (net of tax benefit of $-, $403, $-, and $403) —
(748 ) —
(748 )
Other comprehensive income (loss) (52,144 ) 41,813
27,001
87,744

Comprehensive Income 196,716
455,181
412,060
587,164
Preferred dividend requirements of subsidiaries 3,439
3,446
6,878
6,892
Comprehensive Income Attributable to Entergy Corporation
$193,277

$451,735

$405,182

$580,272

See Notes to Financial Statements.

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2018 and 2017
(Unaudited)
2018 2017
(In Thousands)
OPERATING ACTIVITIES
Consolidated net income
$385,059

$499,420
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization 1,027,609
1,042,671
Deferred income taxes, investment tax credits, and non-current taxes accrued 88,732
(324,227 )
Asset write-offs, impairments, and related charges 51,503
220,828
Gain on sale of assets —
(16,270 )
Changes in working capital:
Receivables (45,515 ) 6,091
Fuel inventory 8,512
6,213
Accounts payable 97,464
9,687
Taxes accrued (8,092 ) (2,202 )
Interest accrued (2,056 ) (3,947 )
Deferred fuel costs (132,263 ) (127,945 )
Other working capital accounts (134,982 ) (91,505 )
Changes in provisions for estimated losses 27,443
(7,340 )
Changes in other regulatory assets 106,712
62,612
Changes in other regulatory liabilities (247,239 ) (8,250 )
Changes in pensions and other postretirement liabilities (181,278 ) (180,346 )
Other 38,314
(265,807 )
Net cash flow provided by operating activities 1,079,923
819,683

INVESTING ACTIVITIES
Construction/capital expenditures (1,885,419 ) (1,719,712 )
Allowance for equity funds used during construction 60,335
41,877
Nuclear fuel purchases (90,321 ) (209,756 )
Proceeds from sale of assets 9,163
100,000
Insurance proceeds received for property damages 10,523
26,157
Changes in securitization account 4,754
10,028
Payments to storm reserve escrow account (2,744 ) (1,124 )
Receipts from storm reserve escrow account —
8,836
Decrease (increase) in other investments (10,769 ) 1,705
Litigation proceeds for reimbursement of spent nuclear fuel storage costs —
25,493
Proceeds from nuclear decommissioning trust fund sales 1,801,170
1,462,698
Investment in nuclear decommissioning trust funds (1,826,384 ) (1,516,406 )
Net cash flow used in investing activities (1,929,692 ) (1,770,204 )

See Notes to Financial Statements.

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2018 and 2017
(Unaudited)
2018 2017
(In Thousands)
FINANCING ACTIVITIES
Proceeds from the issuance of:
Long-term debt 3,359,193
1,036,529
Treasury stock 3,691
7,819
Retirement of long-term debt (2,569,131 ) (866,337 )
Changes in credit borrowings and commercial paper - net 405,795
833,957
Other 10,434
4,305
Dividends paid:
Common stock (321,821 ) (312,209 )
Preferred stock (6,878 ) (6,892 )
Net cash flow provided by financing activities 881,283
697,172

Net increase (decrease) in cash and cash equivalents 31,514
(253,349 )

Cash and cash equivalents at beginning of period 781,273
1,187,844

Cash and cash equivalents at end of period
$812,787

$934,495

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized
$362,629

$334,555
Income taxes
$14,145

($14,673 )

See Notes to Financial Statements.



ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Three Months Ended						Nine Months Ended
	2018			2017			2018			2017
	(In Thousands, Except Share Data)
OPERATING REVENUES
Electric		$2,697,887			$2,793,798			$7,276,374			$7,056,758
Natural gas	26,352			26,585			112,990			100,011
Competitive businesses	380,080			423,245			1,107,606			1,293,867
TOTAL	3,104,319			3,243,628			8,496,970			8,450,636

OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	729,269			612,950			1,638,367			1,426,462
Purchased power	439,380			408,140			1,252,437			1,182,404
Nuclear refueling outage expenses	37,937			43,273			116,057			124,126
Other operation and maintenance	854,013			775,001			2,477,699			2,416,825
Asset write-offs, impairments, and related charges	155,215			16,221			297,082			421,584
Decommissioning	93,829			95,392			285,834			310,062
Taxes other than income taxes	161,916			159,474			485,682			469,090
Depreciation and amortization	324,628			354,739			1,022,099			1,052,332
Other regulatory charges (credits)	37,097			19,435			223,416			(59,314		)
TOTAL	2,833,284			2,484,625			7,798,673			7,343,571

Gain on sale of assets	—			—			—			16,270

OPERATING INCOME	271,035			759,003			698,297			1,123,335

OTHER INCOME
Allowance for equity funds used during construction	32,354			24,338			92,367			65,722
Interest and investment income	177,081			58,332			265,086			194,978
Miscellaneous - net	(43,591		)	(31,335		)	(123,439		)	(78,726		)
TOTAL	165,844			51,335			234,014			181,974

INTEREST EXPENSE
Interest expense	195,311			178,391			570,548			522,857
Allowance for borrowed funds used during construction	(15,244		)	(11,492		)	(43,177		)	(31,057		)
TOTAL	180,067			166,899			527,371			491,800

INCOME BEFORE INCOME TAXES	256,812			643,439			404,940			813,509

Income taxes	(283,006		)	241,795			(519,937		)	(87,555		)

CONSOLIDATED NET INCOME	539,818			401,644			924,877			901,064

Preferred dividend requirements of subsidiaries	3,439			3,446			10,317			10,338

NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION		$536,379			$398,198			$914,560			$890,726

Earnings per average common share:
Basic		$2.96			$2.22			$5.06			$4.96
Diluted		$2.92			$2.21			$5.01			$4.94

Basic average number of common shares outstanding	181,002,303			179,563,819			180,845,440			179,458,914
Diluted average number of common shares outstanding	183,664,583			180,464,069			182,692,325			180,163,074

See Notes to Financial Statements.

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
June 30, 2018 and December 31, 2017
(Unaudited)
2018 2017
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash
$55,197

$56,629
Temporary cash investments 757,590
724,644
Total cash and cash equivalents 812,787
781,273
Accounts receivable:
Customer 662,746
673,347
Allowance for doubtful accounts (14,545 ) (13,587 )
Other 150,084
169,377
Accrued unbilled revenues 460,181
383,813
Total accounts receivable 1,258,466
1,212,950
Deferred fuel costs 114,293
95,746
Fuel inventory - at average cost 174,131
182,643
Materials and supplies - at average cost 752,520
723,222
Deferred nuclear refueling outage costs 172,608
133,164
Prepayments and other 249,645
156,333
TOTAL 3,534,450
3,285,331

OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity 198
198
Decommissioning trust funds 7,217,298
7,211,993
Non-utility property - at cost (less accumulated depreciation) 294,548
260,980
Other 434,066
441,862
TOTAL 7,946,110
7,915,033

PROPERTY, PLANT, AND EQUIPMENT
Electric 47,805,468
47,287,370
Property under capital lease 620,419
620,544
Natural gas 477,715
453,162
Construction work in progress 2,559,790
1,980,508
Nuclear fuel 866,229
923,200
TOTAL PROPERTY, PLANT, AND EQUIPMENT 52,329,621
51,264,784
Less - accumulated depreciation and amortization 21,817,508
21,600,424
PROPERTY, PLANT, AND EQUIPMENT - NET 30,512,113
29,664,360

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $427,427 as of June 30, 2018 and $485,031 as of December 31, 2017) 4,828,973
4,935,689
Deferred fuel costs 239,397
239,298
Goodwill 377,172
377,172
Accumulated deferred income taxes 17,768
178,204
Other 166,666
112,062
TOTAL 5,629,976
5,842,425

TOTAL ASSETS
$47,622,649

$46,707,149

See Notes to Financial Statements.



ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Three Months Ended					Nine Months Ended
	2018			2017		2018			2017
	(In Thousands)

Net Income		$539,818			$401,644		$924,877			$901,064

Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss) (net of tax expense (benefit) of ($8,517), $7,062, ($480), and $17,387)	(32,004		)	13,213		(1,645		)	32,634
Pension and other postretirement liabilities (net of tax expense of $4,126, $6,818, $12,919, and $19,034)	15,265			12,297		47,404			31,845
Net unrealized investment gain (loss) (net of tax expense (benefit) of ($825), $30,644, $1,708, and $72,808)	(1,745		)	33,395		(37,242		)	82,918
Foreign currency translation (net of tax benefit of $-, $-, $-, and $403)	—			—		—			(748		)
Other comprehensive income (loss)	(18,484		)	58,905		8,517			146,649

Comprehensive Income	521,334			460,549		933,394			1,047,713
Preferred dividend requirements of subsidiaries	3,439			3,446		10,317			10,338
Comprehensive Income Attributable to Entergy Corporation		$517,895			$457,103		$923,077			$1,037,375

See Notes to Financial Statements.

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2018 and December 31, 2017
(Unaudited)
2018 2017
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt
$1,016,908

$760,007
Notes payable and commercial paper 1,984,103
1,578,308
Accounts payable 1,459,432
1,452,216
Customer deposits 404,880
401,330
Taxes accrued 206,874
214,967
Interest accrued 185,916
187,972
Deferred fuel costs 32,904
146,522
Obligations under capital leases 1,442
1,502
Pension and other postretirement liabilities 61,580
71,612
Current portion of unprotected excess accumulated deferred income taxes 710,108
—
Other 167,926
221,771
TOTAL 6,232,073
5,036,207

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued 4,434,308
4,466,503
Accumulated deferred investment tax credits 215,369
219,634
Obligations under capital leases 21,263
22,015
Regulatory liability for income taxes-net 1,901,043
2,900,204
Other regulatory liabilities 1,630,335
1,588,520
Decommissioning and asset retirement cost liabilities 6,398,980
6,185,814
Accumulated provisions 505,764
478,273
Pension and other postretirement liabilities 2,739,407
2,910,654
Long-term debt (includes securitization bonds of $483,242 as of June 30, 2018 and $544,921 as of December 31, 2017) 14,857,686
14,315,259
Other 466,189
393,748
TOTAL 33,170,344
33,480,624

Commitments and Contingencies

Subsidiaries' preferred stock without sinking fund 197,771
197,803

COMMON EQUITY
Common stock, $.01 par value, authorized 500,000,000 shares; issued 254,752,788 shares in 2018 and in 2017 2,548
2,548
Paid-in capital 5,429,404
5,433,433
Retained earnings 8,578,276
7,977,702
Accumulated other comprehensive loss (613,642 ) (23,531 )
Less - treasury stock, at cost (73,911,771 shares in 2018 and 74,235,135 shares in 2017) 5,374,125
5,397,637
TOTAL 8,022,461
7,992,515

TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY
$47,622,649

$46,707,149

See Notes to Financial Statements.



ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2018 and 2017
(Unaudited)
	2018			2017
	(In Thousands)
OPERATING ACTIVITIES
Consolidated net income		$924,877			$901,064
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	1,517,344			1,561,565
Deferred income taxes, investment tax credits, and non-current taxes accrued	82,641			(90,607		)
Asset write-offs, impairments, and related charges	210,263			241,838
Gain on sale of assets	—			(16,270		)
Changes in working capital:
Receivables	(153,703		)	(198,029		)
Fuel inventory	49,728			20,746
Accounts payable	79,949			(75,962		)
Taxes accrued	43,510			66,895
Interest accrued	(9,398		)	(6,111		)
Deferred fuel costs	(25,284		)	(117,636		)
Other working capital accounts	(86,063		)	(81,779		)
Changes in provisions for estimated losses	28,599			(10,073		)
Changes in other regulatory assets	207,135			117,430
Changes in other regulatory liabilities	(413,684		)	22,124
Changes in pensions and other postretirement liabilities	(345,526		)	(354,297		)
Other	(250,884		)	(268,147		)
Net cash flow provided by operating activities	1,859,504			1,712,751

INVESTING ACTIVITIES
Construction/capital expenditures	(2,883,047		)	(2,622,104		)
Allowance for equity funds used during construction	92,829			66,437
Nuclear fuel purchases	(170,819		)	(226,054		)
Proceeds from sale of assets	12,915			100,000
Insurance proceeds received for property damages	10,523			26,157
Changes in securitization account	(12,985		)	(6,494		)
Payments to storm reserve escrow account	(4,515		)	(1,925		)
Receipts from storm reserve escrow account	—			8,836
Increase in other investments	(36,140		)	(112,217		)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	—			25,493
Proceeds from nuclear decommissioning trust fund sales	4,177,919			1,902,783
Investment in nuclear decommissioning trust funds	(4,187,161		)	(1,988,634		)
Net cash flow used in investing activities	(3,000,481		)	(2,827,722		)

See Notes to Financial Statements.



ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2018 and 2017
(Unaudited)
	2018			2017
	(In Thousands)
FINANCING ACTIVITIES
Proceeds from the issuance of:
Long-term debt	5,604,131			1,222,606
Treasury stock	24,646			15,121
Retirement of long-term debt	(4,181,820		)	(1,222,915		)
Changes in credit borrowings and commercial paper - net	368,370			937,677
Other	25,540			(337		)
Dividends paid:
Common stock	(482,865		)	(468,396		)
Preferred stock	(10,317		)	(10,338		)
Net cash flow provided by financing activities	1,347,685			473,418

Net increase (decrease) in cash and cash equivalents	206,708			(641,553		)

Cash and cash equivalents at beginning of period	781,273			1,187,844

Cash and cash equivalents at end of period		$987,981			$546,291

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized		$558,381			$507,912
Income taxes		$18,200			($11,883	)

See Notes to Financial Statements.

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Six Months Ended June 30, 2018 and 2017
(Unaudited)

Common Shareholders’ Equity

Subsidiaries’ Preferred Stock
Common
Stock

Treasury
Stock

Paid-in
Capital
Retained Earnings Accumulated Other Comprehensive Income (Loss) Total
(In Thousands)

Balance at December 31, 2016
$—

$2,548

($5,498,584 )
$5,417,245

$8,195,571

($34,971 )
$8,081,809

Consolidated net income (a) 6,892
—
—
—
492,528
—
499,420
Other comprehensive income —
—
—
—
—
87,744
87,744
Common stock issuances related to stock plans —
—
28,367
(7,383 ) —
—
20,984
Common stock dividends declared —
—
—
—
(312,209 ) —
(312,209 )
Preferred dividend requirements of subsidiaries (a) (6,892 ) —
—
—
—
—
(6,892 )

Balance at June 30, 2017
$—

$2,548

($5,470,217 )
$5,409,862

$8,375,890

$52,773

$8,370,856

Balance at December 31, 2017
$—

$2,548

($5,397,637 )
$5,433,433

$7,977,702

($23,531 )
$7,992,515
Implementation of accounting standards —
—
—
—
576,257
(632,617 ) (56,360 )
Balance at January 1, 2018
$—

$2,548

($5,397,637 )
$5,433,433

$8,553,959

($656,148 )
$7,936,155

Consolidated net income (a) 6,878
—
—
—
378,181
—
385,059
Other comprehensive income —
—
—
—
—
27,001
27,001
Common stock issuances related to stock plans —
—
23,512
(4,029 ) —
—
19,483
Common stock dividends declared —
—
—
—
(321,821 ) —
(321,821 )
Preferred dividend requirements of subsidiaries (a) (6,878 ) —
—
—
—
—
(6,878 )
Reclassification pursuant to ASU 2018-02 —
—
—
—
(32,043 ) 15,505
(16,538 )

Balance at June 30, 2018
$—

$2,548

($5,374,125 )
$5,429,404

$8,578,276

($613,642 )
$8,022,461

See Notes to Financial Statements.

(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2018 and 2017 include $6.9 million and $6.9 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.



ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2018 and December 31, 2017
(Unaudited)
	2018			2017
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash		$64,787			$56,629
Temporary cash investments	923,194			724,644
Total cash and cash equivalents	987,981			781,273
Accounts receivable:
Customer	789,633			673,347
Allowance for doubtful accounts	(15,589		)	(13,587		)
Other	166,222			169,377
Accrued unbilled revenues	426,387			383,813
Total accounts receivable	1,366,653			1,212,950
Deferred fuel costs	61,309			95,746
Fuel inventory - at average cost	132,916			182,643
Materials and supplies - at average cost	747,770			723,222
Deferred nuclear refueling outage costs	149,810			133,164
Prepayments and other	248,107			156,333
TOTAL	3,694,546			3,285,331

OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	198			198
Decommissioning trust funds	7,444,346			7,211,993
Non-utility property - at cost (less accumulated depreciation)	302,784			260,980
Other	436,527			441,862
TOTAL	8,183,855			7,915,033

PROPERTY, PLANT, AND EQUIPMENT
Electric	48,362,347			47,287,370
Property under capital lease	620,419			620,544
Natural gas	488,169			453,162
Construction work in progress	2,832,826			1,980,508
Nuclear fuel	846,845			923,200
TOTAL PROPERTY, PLANT, AND EQUIPMENT	53,150,606			51,264,784
Less - accumulated depreciation and amortization	22,057,870			21,600,424
PROPERTY, PLANT, AND EQUIPMENT - NET	31,092,736			29,664,360

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $388,391 as of September 30, 2018 and $485,031 as of December 31, 2017)	4,728,555			4,935,689
Deferred fuel costs	239,446			239,298
Goodwill	377,172			377,172
Accumulated deferred income taxes	21,307			178,204
Other	133,555			112,062
TOTAL	5,500,035			5,842,425

TOTAL ASSETS		$48,471,172			$46,707,149

See Notes to Financial Statements.



ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2018 and December 31, 2017
(Unaudited)
	2018			2017
	(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt		$735,009			$760,007
Notes payable and commercial paper	1,946,677			1,578,308
Accounts payable	1,392,114			1,452,216
Customer deposits	409,153			401,330
Taxes accrued	258,477			214,967
Interest accrued	178,573			187,972
Deferred fuel costs	86,949			146,522
Obligations under capital leases	1,466			1,502
Pension and other postretirement liabilities	57,471			71,612
Current portion of unprotected excess accumulated deferred income taxes	500,419			—
Other	184,255			221,771
TOTAL	5,750,563			5,036,207

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	4,427,744			4,466,503
Accumulated deferred investment tax credits	213,237			219,634
Obligations under capital leases	20,887			22,015
Regulatory liability for income taxes-net	1,802,528			2,900,204
Other regulatory liabilities	1,772,093			1,588,520
Decommissioning and asset retirement cost liabilities	6,555,835			6,185,814
Accumulated provisions	506,959			478,273
Pension and other postretirement liabilities	2,579,270			2,910,654
Long-term debt (includes securitization bonds of $462,889 as of September 30, 2018 and $544,921 as of December 31, 2017)	15,780,827			14,315,259
Other	450,746			393,748
TOTAL	34,110,126			33,480,624

Commitments and Contingencies

Subsidiaries' preferred stock without sinking fund	197,771			197,803

COMMON EQUITY
Common stock, $.01 par value, authorized 500,000,000 shares; issued 254,752,788 shares in 2018 and in 2017	2,548			2,548
Paid-in capital	5,441,696			5,433,433
Retained earnings	8,953,611			7,977,702
Accumulated other comprehensive loss	(632,126		)	(23,531		)
Less - treasury stock, at cost (73,621,473 shares in 2018 and 74,235,135 shares in 2017)	5,353,017			5,397,637
TOTAL	8,412,712			7,992,515

TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY		$48,471,172			$46,707,149

See Notes to Financial Statements.

ENTERGY CORPORATION AND SUBSIDIARIES
SELECTED OPERATING RESULTS
For the Three and Six Months Ended June 30, 2018 and 2017
(Unaudited)

Three Months Ended Increase/
Description 2018 2017 (Decrease) %

(Dollars in Millions)
Utility electric operating revenues:
Residential
$769

$748

$21
3
Commercial 582
604
(22 ) (4 )
Industrial 625
651
(26 ) (4 )
Governmental 57
57
—
—
Total billed retail 2,033
2,060
(27 ) (1 )
Sales for resale 69
46
23
50
Other 228
165
63
38
Total
$2,330

$2,271

$59
3

Utility billed electric energy sales (GWh):
Residential 7,749
7,340
409
6
Commercial 6,943
6,886
57
1
Industrial 12,219
12,209
10
—
Governmental 612
609
3
—
Total retail 27,523
27,044
479
2
Sales for resale 2,566
1,845
721
39
Total 30,089
28,889
1,200
4

Entergy Wholesale Commodities:
Operating revenues
$309

$317

($8 ) (3 )
Billed electric energy sales (GWh) 7,281
6,019
1,262
21

Six Months Ended Increase/
Description 2018 2017 (Decrease) %

(Dollars in Millions)
Utility electric operating revenues:
Residential
$1,661

$1,453

$208
14
Commercial 1,178
1,140
38
3
Industrial 1,222
1,216
6
—
Governmental 113
110
3
3
Total billed retail 4,174
3,919
255
7
Sales for resale 139
124
15
12
Other 265
220
45
20
Total
$4,578

$4,263

$315
7

Utility billed electric energy sales (GWh):
Residential 17,036
14,977
2,059
14
Commercial 13,675
13,325
350
3
Industrial 23,624
23,326
298
1
Governmental 1,220
1,202
18
1
Total retail 55,555
52,830
2,725
5
Sales for resale 5,810
4,867
943
19
Total 61,365
57,697
3,668
6

Entergy Wholesale Commodities:
Operating revenues
$728

$871

($143 ) (16 )
Billed electric energy sales (GWh) 14,277
14,382
(105 ) (1 )



ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Nine Months Ended September 30, 2018 and 2017
(Unaudited)

				Common Shareholders’ Equity
	Subsidiaries’ Preferred Stock			Common Stock		Treasury Stock			Paid-in Capital		Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Total
	(In Thousands)

Balance at December 31, 2016		$—			$2,548		($5,498,584	)		$5,417,245		$8,195,571			($34,971	)		$8,081,809

Consolidated net income (a)	10,338			—		—			—		890,726			—			901,064
Other comprehensive income	—			—		—			—		—			146,649			146,649
Common stock issuances related to stock plans	—			—		36,086			3,363		—			—			39,449
Common stock dividends declared	—			—		—			—		(468,396		)	—			(468,396		)
Preferred dividend requirements of subsidiaries (a)	(10,338		)	—		—			—		—			—			(10,338		)

Balance at September 30, 2017		$—			$2,548		($5,462,498	)		$5,420,608		$8,617,901			$111,678			$8,690,237

Balance at December 31, 2017		$—			$2,548		($5,397,637	)		$5,433,433		$7,977,702			($23,531	)		$7,992,515
Implementation of accounting standards	—			—		—			—		576,257			(632,617		)	(56,360		)
Balance at January 1, 2018		$—			$2,548		($5,397,637	)		$5,433,433		$8,553,959			($656,148	)		$7,936,155

Consolidated net income (a)	10,317			—		—			—		914,560			—			924,877
Other comprehensive income	—			—		—			—		—			8,517			8,517
Common stock issuances related to stock plans	—			—		44,620			8,263		—			—			52,883
Common stock dividends declared	—			—		—			—		(482,865		)	—			(482,865		)
Preferred dividend requirements of subsidiaries (a)	(10,317		)	—		—			—		—			—			(10,317		)
Reclassification pursuant to ASU 2018-02	—			—		—			—		(32,043		)	15,505			(16,538		)

Balance at September 30, 2018		$—			$2,548		($5,353,017	)		$5,441,696		$8,953,611			($632,126	)		$8,412,712

See Notes to Financial Statements.

(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2018 and 2017 include $10.3 million and $10.3 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented within equity.



ENTERGY CORPORATION AND SUBSIDIARIES
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Three Months Ended				Increase/
Description	2018		2017		(Decrease)			%
	(Dollars in Millions)
Utility electric operating revenues:
Residential		$1,139		$1,107		$32		3
Commercial	694		721		(27		)	(4	)
Industrial	683		721		(38		)	(5	)
Governmental	61		62		(1		)	(2	)
Total billed retail	2,577		2,611		(34		)	(1	)
Sales for resale	76		78		(2		)	(3	)
Other	45		105		(60		)	(57	)
Total		$2,698		$2,794		($96	)	(3	)

Utility billed electric energy sales (GWh):
Residential	11,821		10,833		988			9
Commercial	8,726		8,271		455			6
Industrial	12,879		12,503		376			3
Governmental	714		682		32			5
Total retail	34,140		32,289		1,851			6
Sales for resale	2,978		3,387		(409		)	(12	)
Total	37,118		35,676		1,442			4

Entergy Wholesale Commodities:
Operating revenues		$380		$423		($43	)	(10	)
Billed electric energy sales (GWh)	7,576		8,234		(658		)	(8	)


	Nine Months Ended				Increase/
Description	2018		2017		(Decrease)			%
	(Dollars in Millions)
Utility electric operating revenues:
Residential		$2,800		$2,560		$240		9
Commercial	1,871		1,861		10			1
Industrial	1,905		1,937		(32		)	(2	)
Governmental	174		172		2			1
Total billed retail	6,750		6,530		220			3
Sales for resale	215		202		13			6
Other	311		325		(14		)	(4	)
Total		$7,276		$7,057		$219		3

Utility billed electric energy sales (GWh):
Residential	28,857		25,810		3,047			12
Commercial	22,401		21,595		806			4
Industrial	36,503		35,829		674			2
Governmental	1,934		1,885		49			3
Total retail	89,695		85,119		4,576			5
Sales for resale	8,788		8,255		533			6
Total	98,483		93,374		5,109			5

Entergy Wholesale Commodities:
Operating revenues		$1,108		$1,294		($186	)	(14	)
Billed electric energy sales (GWh)	21,853		22,616		(763		)	(3	)

ENTERGY CORPORATION AND SUBSIDIARIES

NOTES TO FINANCIAL STATEMENTS

(Unaudited)

NOTE 1. 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. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. This action followed NRC inspections to review ANO 1’s and ANO 2’s performance in addressing issues that had previously resulted in classification in Column 4.

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. In September 2018 the DOE submitted an offer of judgment to resolve claims in the second round Entergy Nuclear Generation Company case involving Pilgrim. The $62 million offer was accepted by Entergy Nuclear Generation Company, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Nuclear Generation Company. Entergy received payment from the U.S. Treasury in October 2018.

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.

Table of Contents

Entergy Corporation and Subsidiaries

Notes to Financial Statements

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.

~~Table of Contents~~

~~Entergy Corporation and Subsidiaries~~

~~Notes to Financial Statements~~

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.

NOTE 2. 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 status of the proposals the Registrant Subsidiaries made to their regulators for the return of unprotected excess accumulated deferred income taxes to customers, in 2018, Entergy and each of the Registrant Subsidiaries are reclassifying 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 stated that its order was not a final determination and that the APSC had made no decision at that time on the appropriate final accounting or ratemaking treatment of the amounts in question. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its existing formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider includes a netting adjustment that compares actual annual costs and sales to the projected annual costs and sales used to establish rates. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and ~~its~~Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed below, the adjustments to all other riders affected by the Tax Act and to include an amendment for a ~~true up~~true-up mechanism where a rider affected by the Tax Act does not already contain a ~~true up~~true-up mechanism. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018.

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 proceeding 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

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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~~nine-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.

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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. In July 2018 the LPSC issued a proposed rule requiring utilities to adjust rates prospectively to reflect the lower tax rate (either through a formula rate plan or rate case), refund excess tax expense collected since January 1, 2018 until the lower tax rate is reflected in rates (with the refund occurring over one year), and refund excess accumulated deferred income taxes over two years. Entergy Louisiana believes that its formula rate plan settlement, approved in April 2018 and discussed below, addresses fully its obligations regarding the Tax Act and will seek such confirmation in its comments to the proposed rule.

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 to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan are established (September 2018), and this regulatory liability will be returned to customers over the next formula rate plan rate-effective ~~period.~~period (September 2018 through August 2019). As of September 30, 2018, Entergy Louisiana ~~recorded~~has a ~~$55~~$67 million regulatory liability ~~thus far in 2018~~recorded 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 2017 test year filing, which, as discussed below, Entergy Louisiana filed in June 2018.

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.

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In June 2018, Entergy Mississippi and the Mississippi Public Utilities Staff entered into and filed a joint stipulation in Entergy Mississippi’s formula rate plan filing that addressed Entergy Mississippi’s 2018 formula rate plan evaluation report and the ratemaking effects of the Tax Act. InAlso in June 2018 the MPSC approved the stipulation, which provides for incorporating the reduction of the statutory federal income tax rate through the formula rate plan. Entergy Mississippi’s formula rate plan ~~and~~includes a look-back evaluation report filing in March 2019 that will compare actual 2018 results to the allowed return on rate base. The stipulation provides for the flow-back of protected excess accumulated deferred income taxes over approximately 40 years through the formula rate plan. The stipulation also provides for the offset of unprotected excess accumulated deferred income taxes of $127.2 million against net utility plant and $2.2 million against other regulatory assets, and the return to customers of the remaining balance of unprotected excess accumulated deferred income taxes as recovery of a portion of fuel oil inventory and customer bill credits over a ~~3-month~~three-month period from July 2018 through September 2018, with

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any true-up to be reflected in the November 2018 power management rider submittal. Entergy Mississippi recorded the reduction against net utility plant and other regulatory assets in June 2018. In third quarter 2018, Entergy Mississippi returned unprotected excess accumulated deferred income taxes of $25.8 million through customer bill credits and $5.8 million through the sale of fuel oil inventory.

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. 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.

In March 2018, Entergy New Orleans filed its response to ~~that~~the 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. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits starting in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at FERC. The agreement in principle was approved by the City Council in June 2018.

Entergy Texas

As discussed below, in May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflect the inclusion of the federal income tax reductions due to the Tax Act. InSee the discussion below regarding the terms of an unopposed settlement submitted by the parties to the 2018 rate case ~~Entergy Texas proposed to~~that, if approved by the PUCT, establishes the amounts and timing of the return ~~its~~of protected and unprotected excess accumulated deferred income taxes to ~~customers over a two-year period following PUCT approval.~~Entergy Texas customers.

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 proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC

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accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions are ongoing.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

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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. InThe redetermined rate became effective with the first billing cycle of April 2018. Subsequently 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 at ~~this~~that time of the issues suggested by the Attorney General in the proceeding. Following a period of discovery, the Attorney General filed a supplemental response in October 2018 raising new issues with Entergy Arkansas’s March 2018 rate redetermination and asserting that $45.7 million of the increase should be collected subject to refund pending further investigation. Also in October 2018, Entergy Arkansas filed to dismiss the Attorney General’s supplemental response, the APSC general staff filed a motion to strike the Attorney General’s filing, and the Attorney General filed its supplemental response disputing Entergy Arkansas and the APSC staff’s filing.

Entergy Louisiana

In July 2014 the LPSC authorized its staff to initiate an audit of the fuel adjustment clause filings by Entergy Gulf States Louisiana, whose business was combined with Entergy Louisiana in 2015. The ~~redetermined rate became effective with~~audit includes a review of the ~~first billing cycle~~reasonableness of ~~April~~charges flowed through Entergy Gulf States Louisiana’s fuel adjustment clause for the period from 2010 through 2013. Discovery commenced in July 2015. No report of audit has been issued.

In May 2018 the LPSC staff provided notice of audits of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2016 through 2017. Discovery commenced in September 2018. ~~Discovery continues to be conducted by the parties with respect to the redetermined rate.~~No report of audit has been issued.

Entergy Mississippi

Mississippi Attorney General Complaint

As discussed in the Form 10-K the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. The defendants have denied the allegations. In June 2017 the District Court issued a case management order setting a trial date in November 2018. Discovery ended in May 2018. In June 2018, Entergy filed motions for summary judgment, which are currently pending before the District Court. In July 2018 the ~~Mississippi~~ Attorney General filed briefs opposing the summary judgment.

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In September 2018 the District Court held oral arguments on the Entergy companies’ motion to strike the Attorney General’s jury demand. At the hearing, the Attorney General withdrew his opposition to the Entergy companies’ motion to strike the Attorney General’s jury demand. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019.

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 of the Federal District Court ruling to the U.S. Court of Appeals for the Fifth Circuit. Oral argument was held before the Fifth Circuit in February 2018. In April 2018 the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. ~~The State~~In October 2018, Entergy Texas filed a notice of nonsuit in its appeal to the Travis County District Court ~~appeal of~~regarding the PUCT’s January 2016 ~~decision remains pending.~~decision.

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 information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that information.

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Filings with the APSC (Entergy Arkansas)

2018 Formula Rate Plan Filing

In July 2018, Entergy Arkansas filed with the APSC its 2018 formula rate plan filing to set its formula rate for the 2019 calendar year. The filing shows Entergy Arkansas’s projected earned return on common equity for the twelve months ended December 31, 2019 test period to be below the formula rate plan bandwidth. Additionally, the filing includes the first netting adjustment under the current formula rate plan for the historical test year 2017, which is a comparison of projected costs and sales approved in the 2016 formula rate plan filing to actual 2017 costs and sales data. The filing includes a projected $73.4 million revenue deficiency for 2019 and a $95.6 million revenue deficiency for the 2017 historical test year, for a total revenue requirement of $169 million for this filing. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeds the constraint, the resulting increase is limited to four percent of total revenue, which is $65.4 million. ~~Entergy Arkansas recommended that the parties to the proceeding support a~~The matter is scheduled for hearing ~~date~~ in November 2018, and Entergy Arkansas requested that the APSC issue an order approving the proposed formula rate plan adjustment in December 2018, with the proposed formula rate plan adjustment effective with the first billing cycle of January 2019. In October 2018 the APSC staff and intervening parties filed their errors and objections to Entergy Arkansas’s 2018 formula rate plan filing, although no party proposed adjustments that would serve to reduce the requested revenue

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requirement below the annual revenue constraint. Entergy Arkansas also filed its rebuttal to the APSC staff and intervenors in October 2018. Later in October 2018 the parties submitted motions, which are pending with the APSC, to approve a partial settlement as to certain factual issues and to brief certain contested legal issues.

Similar to the 2018 filing, the formula rate plan filing that will be made in 2019 to set the formula rates for the 2020 calendar year will include a netting adjustment that will compare projected costs and sales for 2018 that were approved in the 2017 formula rate plan filing to actual 2018 costs and sales data. To the extent that Entergy Arkansas expects this netting adjustment to reflect actual 2018 revenues that are in excess of the actual costs for that year, Entergy Arkansas will record a regulatory provision in the fourth quarter 2018.

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. In July 2018, Entergy Arkansas filed a settlement, reached by all parties in the APSC proceeding, resolving all ~~issues~~issues. The APSC approved the settlement agreement and ~~seeking an APSC decision no later than September 1,~~restructuring in August 2018. IfEntergy expects to realize a permanent tax benefit at closing, and, pursuant to the ~~appropriate approvals are obtained,~~settlement agreement, Entergy Arkansas ~~expects~~will credit retail customers $39.6 million over six years, beginning in 2019. Entergy Arkansas has also received the required FERC and NRC approvals. The restructuring ~~will be consummated~~is anticipated to close on or before December 1, 2018.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2016 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2017, Entergy Louisiana filed its formula rate plan evaluation report for its 2016 calendar year operations. Rates reflecting the adjustments included in the formula rate plan evaluation report were implemented with the first billing cycle of September 2017, subject to refund. In September 2017 the LPSC issued its report indicating that no changes to Entergy Louisiana’s original formula rate plan evaluation report were required but reserved for several issues, including Entergy Louisiana’s September 2017 update to its formula rate plan evaluation report. In July 2018, Entergy Louisiana and the LPSC staff filed an unopposed joint report setting forth a correction to the annualization calculation, the effect of which was a net $3.5 million revenue requirement reduction, and indicating that there are no outstanding issues with the 2016 formula rate plan report, the supplemental report, or the interim updates. ~~The~~In September 2018 the LPSC ~~voted to accept and approve~~approved the unopposed joint ~~report in August 2018.~~report.

Formula Rate Plan Extension Request

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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:

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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 target 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~~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.

2017 Formula Rate Plan Filing

In June 2018, Entergy Louisiana filed its formula rate plan evaluation report for its 2017 calendar year operations. As stated above under “Formula Rate Plan Extension ~~Request”~~Request,” for the 2017 test year there will be a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year. As such, base rider formula rate plan revenue is to be adjusted prospectively to increase or decrease the earned return on equity fully to the approved cost of equity of 9.95%. The 2017 test year evaluation report produced an earned return on equity of 8.16%, due in large part to revenue-neutral realignments to other recovery mechanisms. Without these realignments, the evaluation report produces an earned return on equity of 9.88% and a resulting base rider formula rate plan revenue increase of $4.8 million. Excluding the Tax Act credits provided for by the tax reform adjustment mechanisms, total formula rate plan revenues will further increase by a total of $98 million as a result of the evaluation report due to adjustments to the additional capacity and MISO cost recovery mechanisms of the formula rate plan, and implementation of the transmission recovery mechanism. In August 2018, Entergy Louisiana filed a supplemental formula rate plan evaluation report to reflect changes from the 2016 test year formula rate plan proceedings, a decrease to the transmission recovery mechanism to reflect lower actual capital additions, and a decrease to evaluation period expenses to reflect the terms of a new power sales agreement. Based on the August 2018 update, Entergy Louisiana would recognize a total decrease in formula rate plan revenue of approximately $17.6 million. Results of the updated 2017 evaluation report filing ~~will be~~were implemented with the September 2018 billing ~~month.~~month subject to refund and review by the LPSC staff and intervenors. In accordance with the terms of the formula rate plan, in September 2018 the LPSC staff and intervenors submitted their responses to Entergy Louisiana’s original formula rate plan evaluation report and supplemental compliance updates. The LPSC staff asserted objections/reservations regarding 1) Entergy Louisiana’s proposed rate adjustments associated with the return of excess accumulated deferred income taxes pursuant to the Tax Act and the treatment of accumulated deferred income taxes related to reductions of rate base; 2) Entergy Louisiana’s reservation regarding treatment of a regulatory asset related to certain special orders by the LPSC; and 3) test year expenses billed from Entergy Services to Entergy Louisiana. Intervenors also objected to Entergy Louisiana’s treatment of the regulatory asset related to certain special orders by the LPSC. A procedural schedule has not yet been established to resolve these issues.

Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a ~~revenue neutral~~revenue-neutral basis intended not to affect the rates of other customer classes.

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Union Power Station and Deactivation or Retirement Decisions for Entergy Louisiana Plants

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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. Entergy Louisiana submitted a compliance filing regarding retirement of Willow Glen 2 and 4, and the LPSC closed the proceeding.

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%. As-filed rates from the supplemental filing were implemented, subject to refund, with customers receiving 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 reduction in the gas infrastructure rider effective with bills rendered on and after the first billing cycle of July 2018. The proceeding is currently in its discovery phase. A procedural schedule has not been established.

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. In June 2018, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a stipulation that confirmed that Entergy Mississippi’s earned returns for both the 2017 look-back filing and 2018 test year were within the respective formula rate plan bandwidths. In June 2018 the MPSC approved the stipulation, which resulted in no change in rates. 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.

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Entergy Mississippi’s formula rate plan includes a look-back evaluation report filing in March 2019 that will compare actual 2018 results to the performance-adjusted allowed return on rate base. To the extent that Entergy Mississippi expects this look-back evaluation report to show the 2018 earned return on rate base exceeded the formula rate plan performance-adjusted bandwidth, Entergy Mississippi will record a regulatory provision in the fourth quarter 2018.

In October 2018, Entergy Mississippi proposed revisions to its formula rate plan that would provide for a mechanism, the interim capacity rate adjustment mechanism, in the formula rate plan to recover the non-fuel related costs of additional owned capacity acquired by Entergy Mississippi, including the non-fuel annual ownership costs of the Choctaw Generating Station, as well as to allow similar cost recovery treatment for other future capacity additions approved by the MPSC.

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~~2019, if the restructuring closed on or before December 1, 2018. In September 2018, Entergy Mississippi and the Mississippi Public Utilities Staff entered into and filed a joint stipulation regarding the restructuring filing. In September 2018 the MPSC issued an order accepting the stipulation in its entirety and approving the restructuring and credits to retail customers of $27 million over six years, consisting of annual payments of $4.5 million for the years 2019-2024. Entergy Mississippi has also received the required FERC and ~~the~~ NRC ~~approvals are obtained,~~approvals. Entergy Mississippi expects the restructuring will be consummated on or before December 1, 2018.

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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.

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Filings with the City Council (Entergy New Orleans)

Energy Smart Programs

As discussed in the Form 10-K, in September 2017, Entergy New Orleans filed a supplemental plan and proposed several options for an interim cost recovery mechanism necessary to recover program costs during the period between when existing funds directed to Energy Smart programs were depleted and when new rates from the ~~anticipated~~then-anticipated 2018 combined rate case (subsequently filed in July 2018), which will include a cost recovery mechanism for Energy Smart funding, take effect (estimated to be August 2019). In December 2017 the City Council approved an energy efficiency cost recovery rider as an interim funding mechanism for Energy Smart, subject to verification that no additional funding sources exist. In June 2018 the City Council also approved a resolution recommending that Entergy New Orleans allocate approximately $13.5 million of benefits resulting from the Tax Act to Energy Smart. Entergy New Orleans is seeking approval of a permanent and stable source of funding for Energy Smart as part of its base rate case filed in July 2018 and revised in September 2018.

Base Rate Case

In July 2018, Entergy New Orleans filed its 2018 base rate case with the City ~~Council.~~Council but withdrew it in August 2018. In September 2018, Entergy New ~~Orleans’s application supports~~Orleans filed a ~~$20~~revised electric and gas base rate case with the City Council. The revised filing requests a 10.5% return on equity for electric operations with opportunity to earn a 10.75% return on equity through a performance adder provision of the electric formula rate plan, and requests a 10.75% return on equity for gas operations. The proposed electric rates in the revised filing reflect a net reduction of $20.3 million. The reduction in electric rates includes a base rate increase of $135.2 million, of which $131.5 million is associated with moving costs currently collected through fuel and riders into base rates, plus a request for an advanced metering surcharge to recover $7.1 million associated with advanced metering infrastructure, offset by a net decrease ~~in total revenue requirement.~~of $31.1 million related to projected fuel and energy efficiency riders. The filing also includes a proposed gas rate decrease of $142 thousand. Entergy New Orleans’s rates reflect the inclusion of federal income tax reductions due to the Tax Act and the provisions of a ~~previously approved~~previously-approved agreement in principle determining how the benefits of the Tax Act would flow. Entergy New Orleans included cost of service studies for electric and gas operations for the twelve months ending December 31, 2017 and the projected twelve months ending December 31, 2018. In addition, Entergy New Orleans included capital additions expected to be placed into service for the period through December 31, 2019. Entergy New Orleans’s request for a change in rates is based on the projected twelve months ending December 31, 2018. ~~For electric rates, that results in a proposed decrease of total revenue requirement of approximately $20 million. For gas rates, that results in a proposed decrease of $129 thousand.~~

~~Entergy New Orleans has requested to restructure~~The filing’s major provisions include: (1) a new electric ~~rates to take into account~~rate structure, which realigns the ~~addition of electric operations in Algiers, such that a single set of rates will be charged in the City of New Orleans, including an increase~~

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~~in its electric customer charges. Entergy New Orleans’s request also includes: a 10.75% return on equity; a three-year formula rate plan for electric (with decoupling) and gas operations, each~~revenue requirement associated with ~~a 100 basis point bandwidth (i.e., 10.75% +/- 50 basis points); realignment of~~ capacity and long-term service agreement expense from certain existing riders to base ~~rates; implementation of riders~~revenue, provides for ~~1) contemporaneous~~the recovery of ~~net~~the cost of advanced metering infrastructure, 2)and partially blends rates for Entergy New Orleans’s customers residing in Algiers with customers residing in the remainder of Orleans Parish through a three-year phase-in; (2) contemporaneous ~~true-up~~cost recovery riders for ~~existing capacity and~~ investments in energy efficiency/demand response, incremental changes in capacity/long-term service agreement ~~expense, as well as new capacity such as power purchase agreements and battery storage (through the purchased power capacity and acquisition cost recovery rider), 3) recovery of distribution~~costs, grid modernization investment, and gas infrastructure replacement ~~program,~~investment; and ~~interim energy efficiency, and 4) permanent recovery mechanism~~(3) formula rate plans for demand-side management activities, including putting into rate base the costs of demand side management activities and contemporaneous recovery of lost contribution to fixed costs; new depreciation rates forboth electric and gas assets; and proposed implementation of new voluntary customer offerings (such as green power, fixed bill, community solar, pre-pay electric and gas service, and electric vehicle charging infrastructure options).operations. The procedural schedule calls for an evidentiary hearing to be held in June 2019.

Filings with the PUCT (Entergy Texas)

2018 Base Rate Case

In May 2018, Entergy Texas filed a base rate case with the PUCT seeking an increase in base rates and rider rates of approximately $166 million, of which $48 million is associated with moving costs currently being collected through riders into base rates such that the total incremental revenue requirement increase is approximately $118 million. Entergy Texas’s proposed rates and revenues reflect the inclusion of federal income tax reductions due to the Tax Act as well as a rider designed to return ~~approximately $202 million of~~ unprotected excess accumulated deferred ~~federal~~ income taxes over a period of two years following PUCT approval. The base rate case is based on a 12-month test year ending December 31, 2017.

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In addition, Entergy Texas included capital additions placed into service for the period of April 1, 2013 through December 31, 2017, as well as a post-test year adjustment to include capital additions placed in service by June 30, 2018. ~~A hearing~~In October 2018 the parties filed an unopposed settlement resolving all issues in the proceeding, supporting testimony, a proposed order approving the settlement, and a motion for interim rates effective for usage on and after October 17, 2018. The unopposed settlement reflects the ~~merits~~following terms: a base rate increase of $53.2 million (net of costs realigned from riders), a $25 million refund to reflect the lower federal income tax rate applicable to Entergy Texas from January 25, 2018 through the date new rates are implemented, $6 million of capitalized skylining tree hazard costs will not be recovered from customers, $242.5 million of protected excess accumulated deferred income taxes, which includes a tax gross-up, will be returned to customers through base rates under the average rate assumption method over the lives of the associated assets, and $185.2 million of unprotected excess accumulated deferred income taxes, which includes a tax gross-up, will be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider will include carrying charges and will be in effect over a period of 12 months for large industrial customers and over a period of four years for other customers. The settlement, if approved by the PUCT, would provide final resolution of all issues in the matter, including those related to the Tax Act. In October 2018 the ALJ granted the unopposed motion for interim rates to be effective for service rendered on or after October 17, 2018. The unopposed settlement is ~~scheduled in August 2018.~~pending consideration by the PUCT.

Advanced Metering Infrastructure (AMI) Filings

Entergy Mississippi

See the Form 10-K for discussion of the MPSC order finding that Entergy Mississippi’s deployment of AMI is in the public interest and granting a certificate of public convenience and necessity. In June 2018, as part of the order approving the joint stipulation between the Mississippi Public Utilities Staff and Entergy Mississippi addressing Entergy Mississippi’s 2018 formula rate plan evaluation report and the ratemaking effects of the Tax Act, the MPSC approved the acceleration of the recovery of substantially all of Entergy Mississippi’s existing customer meters in anticipation of AMI deployment.

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 fourth quarter 2018. In April 2018 the City Council adopted a resolution directing Entergy New Orleans to explore the options for accelerating the deployment of AMI. In June 2018 the City Council approved a one year acceleration of AMI in its service area for an incremental $4.4 million, bringing the total capital spending related to AMI for Entergy New Orleans to $79.4 million.

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

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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 its brief arguing that the FERC should require the Utility operating companies to issue refunds for the 20-month refund period from September 2001 to May 2003. In May 2018, Entergy filed its brief arguing that the FERC should not require the Utility operating companies to issue refunds for the 20-month refund period from September 2001 to May 2003.

Also as discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation

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of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies:



	Payments (Receipts)
	(In Millions)
Entergy Arkansas	($4)
Entergy Louisiana	($23)
Entergy Mississippi	$16
Entergy New Orleans	$5
Entergy Texas	$6

These payments were made in July 2018.

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. Entergy filed in May 2018 the bandwidth true-up payments and receipts for the 2011-2014 rate filings (table does not net to zero due to rounding):



	Payments (Receipts)
	(In Millions)
Entergy Arkansas	$3
Entergy Louisiana	$3
Entergy Mississippi	($1)
Entergy New Orleans	$1
Entergy Texas	($5)

These payments were made in May 2018.

Utility Operating Company Termination of System Agreement Participation

As discussed in the Form 10-K, Entergy Arkansas and Entergy Mississippi ceased participating in the System Agreement effective December 18, 2013 and November 7, 2015, respectively. Entergy Louisiana, Entergy New Orleans, and Entergy Texas terminated participation in the System Agreement on August 31, 2016, which resulted in the termination of the System Agreement in its entirety pursuant to a settlement agreement approved by the FERC in December 2015.

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In December 2013 the FERC set one issue for hearing involving whether and how the benefits associated with settlement with Union Pacific regarding certain coal delivery issues should be allocated among Entergy Arkansas and the other Utility operating companies post-termination of the System Agreement. In December 2014 a FERC ALJ issued an initial decision finding that Entergy Arkansas would realize benefits after December 18, 2013 from the 2008 settlement agreement between Entergy Services, Entergy Arkansas, and Union Pacific, related to certain coal delivery issues. In March 2016 the FERC issued an opinion affirming the December 2014 initial decision with regard to the determination that there were benefits related to the Union Pacific settlement, which were realized post-Entergy Arkansas’s December 2013 withdrawal from the System Agreement, that should be shared with the other Utility operating companies utilizing the methodology proposed by the MPSC and trued-up to actual coal volumes purchased. In May 2016, Entergy made a compliance filing that provided the calculation of Union Pacific settlement benefits utilizing the methodology adopted by the initial decision, trued-up for the actual volumes of coal purchased. The payments were made in May 2016. In August 2016 the FERC issued an order accepting Entergy’s compliance filing. Also in August 2016 the APSC filed a petition for review of the FERC’s March 2016 and August 2016 orders with the U.S. Court of Appeals for the D.C. Circuit. In June 2018 the D.C. Circuit denied the APSC’s petition.

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. In May 2018 the D.C. Circuit denied the LPSC’s rehearing request. In August 2018 the LPSC filed with the Supreme Court of the United States a petition for a writ of certiorari to review the judgment of the D.C. Circuit.

Entergy Arkansas Opportunity Sales Proceeding

See the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding filed with the FERC. In October 2018 the FERC issued an order addressing the ALJ’s July 2017 initial decision. The FERC reversed the ALJ’s decision to cap the reduction in Entergy Arkansas’s payment to account for the increased bandwidth payments that Entergy Arkansas made to the other operating companies. The FERC also reversed the ALJ’s decision that Grand Gulf sales from January through September 2000 should be included in the calculation of Entergy Arkansas’s payment. The FERC affirmed on other grounds the ALJ’s rejection of the LPSC’s claim that certain joint account sales should be accounted for as part of the calculation of Entergy Arkansas’s payment. The FERC directed Entergy to make a compliance filing by December 17, 2018 providing a final calculation of Entergy Arkansas’s payments to the other Utility operating companies pursuant to the findings in the order and explaining how Entergy Arkansas will pay refunds, including the timeline for making those refunds. The FERC’s decision effectively establishes the base amount Entergy Arkansas must pay to the other Utility operating companies for the period of 2000-2009 to be approximately $68 million. Entergy Arkansas will also pay interest on the base amount to the other Utility operating companies, currently estimated to be approximately $64 million as of September 30, 2018 for an estimated total of $132 million. This amount is consistent with the liability previously recognized by Entergy Arkansas. The December 2018 compliance filing will include the recipients and final amount of payments owed by Entergy Arkansas, as well as the timing of the payments. Because management currently expects to recover the retail portion of the payments due as a result of this proceeding, Entergy Arkansas previously recognized a regulatory asset with a balance of $114 million as of September 30, 2018.

Complaints Against System Energy

Return on Equity Complaints

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pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. Entergy Arkansas also sells some of its Grand Gulf capacity and energy to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans under separate agreements. The current return on equity under the Unit Power Sales Agreement is 10.94%, which was established in a rate proceeding that became final in July 2001.

The APSC and MPSC complaint alleges that the return on equity is unjust and unreasonable because current capital market and other considerations indicate that it is excessive. The complaint requests the FERC to institute proceedings to investigate the return on equity and establish a lower return on equity, and also requests that the FERC establish January 23, 2017 as a refund effective date. The complaint includes return on equity analysis that purports to establish that the range of reasonable return on equity for System Energy is between 8.37% and 8.67%. System Energy answered the complaint in February 2017 and disputes that a return on equity of 8.37% to 8.67% is just and reasonable. The LPSC and the City Council intervened in the proceeding expressing support for the complaint. System Energy is recording a provision against revenue for the potential outcome of this proceeding. 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 below, and directed the parties to engage in settlement proceedings before an ALJ. The parties have been unable to settle the return on equity issue and a FERC hearing judge was assigned in July 2018. ~~A prehearing conference is scheduled for August 21, 2018.~~ The 15-month 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. The APSC, MPSC, and City Council intervened in the proceeding, filed an answer expressing support for the complaint, and asked the FERC to consolidate this proceeding with the proceeding initiated by the complaint of the APSC and MPSC in January 2017. System Energy answered the LPSC complaint in May 2018 and also filed a motion to dismiss the complaint. In July 2018 the LPSC answered System Energy’s motion to dismiss.

In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing System Energy’s return on equity, with a refund effective date of April 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The consolidated hearing was scheduled for June 2019, but the procedural schedule is currently being held in abeyance. An ALJ ordered the abeyance after the FERC, in a separate proceeding on the return on equity for New England transmission owners, issued an order modifying its standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC docketed the amended complaint in a new proceeding, and System Energy submitted a response to the amended complaint in October 2018.

Grand Gulf Sale-leaseback Renewal Complaint

In May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal in 2015 of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. The complaint alleges that System Energy violated the filed rate and the FERC’s ratemaking and accounting requirements when it included in Unit Power Sales Agreement billings the cost of capital additions associated with the sale-leaseback interest, and that System Energy is double-recovering costs by including both the lease payments and the capital additions in Unit Power Sales Agreement billings. The complaint also claims that System Energy was imprudent in entering into the sale-leaseback renewal because the Utility operating

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companies that purchase Grand Gulf’s output from System Energy could have obtained cheaper capacity and energy in the MISO markets. The complaint further alleges that System Energy violated various other reporting and accounting requirements and should have sought prior FERC approval of the lease renewal. The complaint seeks various forms

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of relief from the FERC. The complaint seeks refunds for capital addition costs for all years in which they were recorded in allegedly non-formula accounts or, alternatively, the disallowance of the return on equity for the capital additions in those years plus interest. The complaint also asks that the FERC disallow and refund the lease costs of the sale-leaseback renewal on grounds of imprudence, investigate System Energy’s treatment of a DOE litigation payment, and impose certain forward-looking procedural protections, including audit rights for retail regulators of the Unit Power Sales Agreement formula rates. The APSC, MPSC, and City Council have intervened in the proceeding.

In June 2018, System Energy and Entergy Services filed a motion to dismiss and answer to the LPSC complaint denying that System Energy’s treatment of the sale-leaseback renewal and capital additions violated the terms of the filed rate or any other FERC ratemaking, accounting, or legal requirements or otherwise constituted double recovery. The response also argued that the complaint is inconsistent with a FERC-approved settlement to which the LPSC is a party and that explicitly authorizes System Energy to recover its lease payments. Finally, the response argued that both the capital additions and the sale-leaseback renewal were prudent investments and the LPSC complaint fails to justify any disallowance or refunds. The response asked that the FERC dismiss and reject the LPSC complaint without further action, investigation, or hearing, but also offered to submit formula rate protocols for the Unit Power Sales Agreement similar to the procedures used for reviewing transmission rates under the MISO tariff. In September 2018 the FERC issued an order setting the complaint for hearing and settlement proceedings. The FERC established a refund effective date of May 2018.

Unit Power Sales Agreement

As discussed in the Form 10-K, in August 2017, System Energy submitted to the FERC proposed limited amendments to the Unit Power Sales Agreement to adopt (1) updated rates for use in calculating Grand Gulf plant depreciation and amortization expenses and (2) updated nuclear decommissioning cost annual revenue requirements, both of which are recovered through the Unit Power Sales Agreement rate formula. The proposed amendments would result in lower charges to the Utility operating companies that buy capacity and energy from System Energy under the Unit Power Sales Agreement. The FERC accepted the proposed amendments effective October 1, 2017, and established a refund effective date of October 11, 2017 with respect to the rate decrease. In June 2018, System Energy filed with the FERC an uncontested settlement relating to the updated depreciation rates and nuclear decommissioning cost annual revenue requirements. In August 2018 the FERC issued an order accepting the settlement. In third quarter 2018, System Energy recorded a reduction in depreciation expense of approximately $26 million, representing the cumulative difference in depreciation expense resulting from the depreciation rates used from October 11, 2017 through September 30, 2018 and the depreciation rates included in the settlement filing accepted by the FERC.

Storm Cost Recovery Filings with Retail Regulators

Entergy Mississippi

As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million, the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million. As of June 30, 2018, Entergy Mississippi’s storm damage provision balance exceeded $15 million. Accordingly the storm damage provision ~~will~~was reset to zero beginning with August 2018 bills.

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NOTE 3. EQUITY (Entergy Corporation and Entergy Louisiana)

Common Stock

Earnings per Share

The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements:


	For the Three Months Ended June 30,												For the Three Months Ended September 30,
	2018						2017						2018						2017
	(In Millions, Except Per Share Data)												(In Millions, Except Per Share Data)
Basic earnings per share	Income		Shares	$/share			Income		Shares	$/share			Income		Shares	$/share			Income		Shares	$/share
Net income attributable to Entergy Corporation		$245.4	180.8		$1.36			$409.9	179.5		$2.28			$536.4	181.0		$2.96			$398.2	179.6		$2.22
Average dilutive effect of:
Stock options			0.3	—					0.2	—					0.4	(0.01		)			0.2	—
Other equity plans			0.7	(0.01		)			0.5	(0.01		)			0.8	(0.01		)			0.7	(0.01		)
Equity forwards			1.2	(0.01		)			—	—					1.5	(0.02		)			—	—
Diluted earnings per share		$245.4	183.0		$1.34			$409.9	180.2		$2.27			$536.4	183.7		$2.92			$398.2	180.5		$2.21

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.1 million for the three months ended ~~June~~September 30, 2018 and approximately 2.5 million for the three months ended ~~June~~September 30, 2017.


	For the Six Months Ended June 30,												For the Nine Months Ended September 30,
	2018						2017						2018						2017
	(In Millions, Except Per Share Data)												(In Millions, Except Per Share Data)
Basic earnings per share	Income		Shares	$/share			Income		Shares	$/share			Income		Shares	$/share			Income		Shares	$/share
Net income attributable to Entergy Corporation		$378.2	180.8		$2.09			$492.5	179.4		$2.75			$914.6	180.8		$5.06			$890.7	179.5		$4.96
Average dilutive effect of:
Stock options			0.3	—					0.2	—					0.3	(0.01		)			0.2	(0.01		)
Other equity plans			0.5	—					0.4	(0.01		)			0.7	(0.01		)			0.5	(0.01		)
Equity forwards			0.6	(0.01		)			—	—					0.9	(0.03		)			—	—
Diluted earnings per share		$378.2	182.2		$2.08			$492.5	180.0		$2.74			$914.6	182.7		$5.01			$890.7	180.2		$4.94

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.1 million for the ~~six~~nine months ended ~~June~~September 30, 2018 and approximately ~~3.7~~3.3 million for the ~~six~~nine months ended ~~June~~September 30, 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.

Dividends declared per common share were $0.89 for the three months ended September 30, 2018 and $0.87 for the three months ended September 30, 2017. Dividends declared per common share were $2.67 for the nine months ended September 30, 2018 and $2.61 for the nine months ended September 30, 2017.

Equity Forward Sale Agreements

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amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forwards occur. The equity forwards require Entergy to, at its election prior to June 7, 2019, either (i) physically settle the transactions by issuing the total of 15.3 million shares of its common stock to the investment banks

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in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially $74.45 per share) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreements.

If Entergy elects physical settlement of the forward sale agreements, it expects to use the net proceeds for general corporate purposes, which may include repayment of commercial paper, outstanding loans under Entergy's revolving credit facility, or other debt.

Until settlement of the equity forwards, earnings per share dilution resulting from the agreements, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. If Entergy had elected to net share settle the forward sale agreements as of ~~June~~September 30, 2018, Entergy would have been required to deliver ~~1.2~~1.4 million shares.

Treasury Stock

During the ~~six~~nine months ended ~~June~~September 30, 2018, Entergy Corporation issued ~~323,364~~613,662 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards. Entergy Corporation did not repurchase any of its common stock during the ~~six~~nine months ended ~~June~~September 30, 2018.

Retained Earnings

On ~~July 27,~~October 26, 2018, Entergy Corporation’s Board of Directors declared a common stock dividend of ~~$0.89~~$0.91 per share, payable on ~~September 4,~~December 3, 2018, to holders of record as of ~~August 9,~~November 8, 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

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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.

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Comprehensive Income

Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended ~~June~~September 30, 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)			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)												(In Thousands)
Beginning balance, April 1, 2018		$50,194			($605,491	)		($6,201	)		($561,498	)
Beginning balance, July 1, 2018														($14,874	)		($589,926	)		($8,842	)		($613,642	)
Other comprehensive income (loss) before reclassifications	(62,981		)	—			(7,509		)	(70,490		)	(40,401		)	—			(7,173		)	(47,574		)
Amounts reclassified from accumulated other comprehensive income (loss)	(2,087		)	15,565			4,868			18,346			8,397			15,265			5,428			29,090
Net other comprehensive income (loss) for the period	(65,068		)	15,565			(2,641		)	(52,144		)	(32,004		)	15,265			(1,745		)	(18,484		)
Ending balance, June 30, 2018		($14,874	)		($589,926	)		($8,842	)		($613,642	)
Ending balance, September 30, 2018														($46,878	)		($574,661	)		($10,587	)		($632,126	)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended ~~June~~September 30, 2017 by component:


	Cash flow hedges net unrealized gain (loss)			Pension and other postretirement liabilities			Net unrealized investment gain (loss)			Foreign currency translation			Total Accumulated Other Comprehensive Income (Loss)			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)															(In Thousands)
Beginning balance, April 1, 2017		$3,465			($460,814	)		$467,561			$748			$10,960
Beginning balance, July 1, 2017																	$23,414			($449,898	)		$479,257			$52,773
Other comprehensive income (loss) before reclassifications	28,057			—			33,870			(748		)	61,179			27,884			—			35,630			63,514
Amounts reclassified from accumulated other comprehensive income (loss)	(8,108		)	10,916			(22,174		)	—			(19,366		)	(14,671		)	12,297			(2,235		)	(4,609		)
Net other comprehensive income (loss) for the period	19,949			10,916			11,696			(748		)	41,813			13,213			12,297			33,395			58,905
Ending balance, June 30, 2017		$23,414			($449,898	)		$479,257			$—			$52,773
Ending balance, September 30, 2017																	$36,627			($437,601	)		$512,652			$111,678

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The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the ~~six~~nine months ended ~~June~~September 30, 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)			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)												(In Thousands)

Ending balance, December 31, 2017		($37,477	)		($531,099	)		$545,045			($23,531	)		($37,477	)		($531,099	)		$545,045			($23,531	)
Implementation of accounting standards	—			—			(632,617		)	(632,617		)	—			—			(632,617		)	(632,617		)
Beginning balance, January 1, 2018		($37,477	)		($531,099	)		($87,572	)		($656,148	)		($37,477	)		($531,099	)		($87,572	)		($656,148	)

Other comprehensive income (loss) before reclassifications	8,585			—			(43,785		)	(35,200		)	(31,816		)	—			(50,958		)	(82,774		)
Amounts reclassified from accumulated other comprehensive income (loss)	21,774			32,139			8,288			62,201			30,171			47,404			13,716			91,291
Net other comprehensive income (loss) for the period	30,359			32,139			(35,497		)	27,001			(1,645		)	47,404			(37,242		)	8,517

Reclassification pursuant to ASU 2018-02	(7,756		)	(90,966		)	114,227			15,505			(7,756		)	(90,966		)	114,227			15,505

Ending balance, June 30, 2018		($14,874	)		($589,926	)		($8,842	)		($613,642	)
Ending balance, September 30, 2018														($46,878	)		($574,661	)		($10,587	)		($632,126	)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the ~~six~~nine months ended ~~June~~September 30, 2017 by component:


	Cash flow hedges net unrealized gain (loss)			Pension and other postretirement liabilities			Net unrealized investment gain (loss)			Foreign currency translation			Total Accumulated Other Comprehensive Income (Loss)			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)															(In Thousands)
Beginning balance, January 1, 2017		$3,993			($469,446	)		$429,734			$748			($34,971	)		$3,993			($469,446	)		$429,734			$748			($34,971	)
Other comprehensive income (loss) before reclassifications	60,665			—			73,742			(748		)	133,659			88,550			—			109,372			(748		)	197,174
Amounts reclassified from accumulated other comprehensive income (loss)	(41,244		)	19,548			(24,219		)	—			(45,915		)	(55,916		)	31,845			(26,454		)	—			(50,525		)
Net other comprehensive income (loss) for the period	19,421			19,548			49,523			(748		)	87,744			32,634			31,845			82,918			(748		)	146,649
Ending balance, June 30, 2017		$23,414			($449,898	)		$479,257			$—			$52,773
Ending balance, September 30, 2017																	$36,627			($437,601	)		$512,652			$—			$111,678

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The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended ~~June~~September 30, 2018 and 2017:


	Pension and Other Postretirement Liabilities						Pension and Other Postretirement Liabilities
	2018			2017			2018			2017
	(In Thousands)						(In Thousands)
Beginning balance, April 1,		($56,950	)		($48,812	)
Beginning balance, July 1,								($57,451	)		($49,122	)
Amounts reclassified from accumulated other comprehensive income (loss)	(501		)	(310		)	(500		)	(370		)
Net other comprehensive income (loss) for the period	(501		)	(310		)	(500		)	(370		)

Ending balance, June 30,		($57,451	)		($49,122	)
Ending balance, September 30,								($57,951	)		($49,492	)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017:


	Pension and Other Postretirement Liabilities						Pension and Other Postretirement Liabilities
	2018			2017			2018			2017
	(In Thousands)						(In Thousands)
Beginning balance, January 1,		($46,400	)		($48,442	)		($46,400	)		($48,442	)
Amounts reclassified from accumulated other comprehensive income (loss)	(1,002		)	(680		)	(1,502		)	(1,050		)
Net other comprehensive income (loss) for the period	(1,002		)	(680		)	(1,502		)	(1,050		)

Reclassification pursuant to ASU 2018-02	(10,049		)	—			(10,049		)	—

Ending balance, June 30,		($57,451	)		($49,122	)
Ending balance, September 30,								($57,951	)		($49,492	)

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Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended ~~June~~September 30, 2018 and 2017 are as follows:


	Amounts reclassified from AOCI						Income Statement Location	Amounts reclassified from AOCI						Income Statement Location
	2018			2017				2018			2017
	(In Thousands)							(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts		$2,735			$12,695		Competitive business operating revenues		($10,566	)		$22,756		Competitive business operating revenues
Interest rate swaps	(93		)	(219		)	Miscellaneous - net	(63		)	(185		)	Miscellaneous - net
Total realized gain (loss) on cash flow hedges	2,642			12,476				(10,629		)	22,571
	(555		)	(4,368		)	Income taxes	2,232			(7,900		)	Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)		$2,087			$8,108				($8,397	)		$14,671

Pension and other postretirement liabilities
Amortization of prior-service credit		$5,424			$6,564		(a)		$5,425			$6,565		(a)
Amortization of loss	(24,808		)	(21,554		)	(a)	(24,740		)	(21,480		)	(a)
Settlement loss	(406		)	(1,765		)	(a)	(76		)	(4,200		)	(a)
Total amortization	(19,790		)	(16,755		)		(19,391		)	(19,115		)
	4,225			5,839			Income taxes	4,126			6,818			Income taxes
Total amortization (net of tax)		($15,565	)		($10,916	)			($15,265	)		($12,297	)

Net unrealized investment gain (loss)
Realized gain (loss)		($7,702	)		$43,479		Interest and investment income		($8,589	)		$4,382		Interest and investment income
	2,834			(21,305		)	Income taxes	3,161			(2,147		)	Income taxes
Total realized investment gain (loss) (net of tax)		($4,868	)		$22,174				($5,428	)		$2,235

Total reclassifications for the period (net of tax)		($18,346	)		$19,366				($29,090	)		$4,609


(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.

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Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017 are as follows:


	Amounts reclassified from AOCI						Income Statement Location	Amounts reclassified from AOCI						Income Statement Location
	2018			2017				2018			2017
	(In Thousands)							(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts		($27,347	)		$63,922		Competitive business operating revenues		($37,913	)		$86,678		Competitive business operating revenues
Interest rate swaps	(215		)	(469		)	Miscellaneous - net	(278		)	(654		)	Miscellaneous - net
Total realized gain (loss) on cash flow hedges	(27,562		)	63,453				(38,191		)	86,024
	5,788			(22,209		)	Income taxes	8,020			(30,108		)	Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)		($21,774	)		$41,244				($30,171	)		$55,916

Pension and other postretirement liabilities
Amortization of prior-service credit		$10,850			$13,126		(a)		$16,278			$19,691		(a)
Amortization of loss	(49,760		)	(43,125		)	(a)	(74,503		)	(64,605		)	(a)
Settlement loss	(2,022		)	(1,765		)	(a)	(2,098		)	(5,965		)	(a)
Total amortization	(40,932		)	(31,764		)		(60,323		)	(50,879		)
	8,793			12,216			Income taxes	12,919			19,034			Income taxes
Total amortization (net of tax)		($32,139	)		($19,548	)			($47,404	)		($31,845	)

Net unrealized investment gain (loss)
Realized gain (loss)		($13,114	)		$47,489		Interest and investment income		($21,703	)		$51,871		Interest and investment income
	4,826			(23,270		)	Income taxes	7,987			(25,417		)	Income taxes
Total realized investment gain (loss) (net of tax)		($8,288	)		$24,219				($13,716	)		$26,454

Total reclassifications for the period (net of tax)		($62,201	)		$45,915				($91,291	)		$50,525


(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.

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Notes to Financial Statements

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended ~~June~~September 30, 2018 and 2017 are as follows:


	Amounts reclassified from AOCI						Income Statement Location	Amounts reclassified from AOCI						Income Statement Location
	2018			2017				2018			2017
	(In Thousands)							(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service credit		$1,934			$1,934		(a)		$1,934			$1,934		(a)
Amortization of loss	(1,256		)	(1,332		)	(a)	(1,257		)	(1,332		)	(a)
Total amortization	678			602				677			602
	(177		)	(292		)	Income taxes	(177		)	(232		)	Income taxes
Total amortization (net of tax)	501			310				500			370

Total reclassifications for the period (net of tax)		$501			$310				$500			$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.

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017 are as follows:


	Amounts reclassified from AOCI						Income Statement Location	Amounts reclassified from AOCI						Income Statement Location
	2018			2017				2018			2017
	(In Thousands)							(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service credit		$3,868			$3,868		(a)		$5,802			$5,802		(a)
Amortization of loss	(2,513		)	(2,664		)	(a)	(3,770		)	(3,996		)	(a)
Total amortization	1,355			1,204				2,032			1,806
	(353		)	(524		)	Income taxes	(530		)	(756		)	Income taxes
Total amortization (net of tax)	1,002			680				1,502			1,050

Total reclassifications for the period (net of tax)		$1,002			$680				$1,502			$1,050


(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.

NOTE 4. 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)

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Notes to Financial Statements


Capacity	Borrowings	Letters of Credit	Capacity Available	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$390	$6	$3,104	$630	$6	$2,864

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 ~~June~~September 30, 2018, Entergy Corporation had approximately ~~$1,945~~$1,947 million of commercial paper outstanding. The weighted-average interest rate for the ~~six~~nine months ended ~~June~~September 30, 2018 was ~~2.31%~~2.42%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of ~~June~~September 30, 2018 as follows:



Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of ~~June~~September 30, 2018	Letters of Credit Outstanding as of ~~June~~September 30, 2018
Entergy Arkansas	April 2019	$20 million (b)	~~3.34%~~3.49%	$—	$—
Entergy Arkansas	~~August 2022~~September 2023	$150 million (c)	~~3.34%~~3.49%	$—	$—
Entergy Louisiana	~~August 2022~~September 2023	$350 million (c)	~~3.34%~~3.49%	$—	$~~9.1 million~~—
Entergy Mississippi	May 2019	$37.5 million (d)	~~3.59%~~3.74%	$—	$—
Entergy Mississippi	May 2019	$35 million (d)	~~3.59%~~3.74%	$—	$—
Entergy Mississippi	May 2019	$10 million (d)	~~3.59%~~3.74%	$—	$—
Entergy New Orleans	November 2018	$25 million (c)	~~3.57%~~3.72%	$—	$0.8 million
Entergy Texas	~~August 2022~~September 2023	$150 million (c)	~~3.59%~~3.74%	$—	$~~24.4~~1.3 million


(a)	For credit facilities with no borrowings as of ~~June~~September 30, 2018, the interest rate is the estimated interest rate as of ~~June~~September 30, 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.


(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.

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 ~~June~~September 30, 2018:

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Company	Amount of Uncommitted Facility	Letter of Credit Fee	Letters of Credit Issued as of ~~June~~September 30, 2018 (a)
Entergy Arkansas	$25 million	0.70%	$1 million
Entergy Louisiana	$125 million	0.70%	$~~37.8~~22 million
Entergy Mississippi	$40 million	0.70%	$~~20.2~~11.2 million
Entergy New Orleans	$15 million	1.00%	$~~7.4~~2.1 million
Entergy Texas	$50 million	0.70%	$~~12.5~~20 million


(a)	As of ~~June~~September 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of ~~$0.6~~$1 million for Entergy Arkansas, ~~and~~ $0.2 million for Entergy ~~Mississippi.~~Mississippi, and $3.6 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 ~~June~~September 30, 2018 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:


	Authorized	Borrowings	Authorized	Borrowings
	(In Millions)		(In Millions)
Entergy Arkansas	$250	$—	$250	$—
Entergy Louisiana	$450	$—	$450	$—
Entergy Mississippi	$175	$63	$175	$34
Entergy New Orleans	$150	$23	$150	$—
Entergy Texas	$200	$—	$200	$—
System Energy	$200	$—	$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 ~~June~~September 30, 2018, ~~$108~~$132 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the ~~six~~nine months ended ~~June~~September 30, 2018 was ~~3.26%~~3.37% 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 ~~June~~September 30, 2018 as follows:

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Notes to Financial Statements


Company	Expiration Date	Amount of Facility	Weighted Average Interest Rate on Borrowings (a)	Amount Outstanding as of June 30, 2018	Expiration Date	Amount of Facility	Weighted Average Interest Rate on Borrowings (a)	Amount Outstanding as of September 30, 2018
		(Dollars in Millions)				(Dollars in Millions)
Entergy Arkansas VIE	May 2019	$80	3.08%	$41.7	September 2021	$80	3.18%	$70.4
Entergy Louisiana River Bend VIE	May 2019	$105	3.09%	$44.8	September 2021	$105	3.18%	$34.5
Entergy Louisiana Waterford VIE	May 2019	$85	3.07%	$45.4	September 2021	$105	3.18%	$30.5
System Energy VIE	May 2019	$120	3.79%	$38.9 (b)	September 2021	$120	3.18%	$37.7


(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 June 30, 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 ~~June~~September 30, 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 Arkansas)

In May 2018, Entergy Arkansas issued $250 million of 4.00% Series first mortgage bonds due June 2028. Entergy Arkansas expects to use the proceeds, together with other funds, to redeem ~~$9.4~~$9.35 million of its 4.72% Series preferred stock, $7 million of its 4.32% Series preferred stock, and $15 million of its 4.56% Series preferred ~~stock;~~stock, and for general corporate purposes.

(Entergy Louisiana)

In March 2018, Entergy Louisiana issued $750 million of 4.00% collateral trust mortgage bonds due March 2033. Entergy Louisiana used a portion of the proceeds to repay at maturity its $375 million of 6.0% Series first mortgage bonds due May 2018; to repay borrowings from the money pool; and to repay borrowings under its $350

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million credit facility. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power ~~Station;~~Station, and for general corporate purposes.

In August 2018, Entergy Louisiana issued $600 million of 4.20% collateral trust mortgage bonds due September 2048. Entergy Louisiana used a portion of the proceeds to repay at maturity its $300 million of 6.5% Series first mortgage bonds due September 2018. The remaining proceeds, together with other funds, are being used to finance the construction of the Lake Charles Power Station and St. Charles Power Station, and for general corporate purposes.

(Entergy New Orleans)

In September 2018, Entergy New Orleans issued $60 million of 4.51% Series first mortgage bonds due September 2033. Entergy New Orleans is using the proceeds 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.

In October 2018 the System Energy nuclear fuel trust variable interest entity paid, at maturity, its $85 million of 3.78% Series I notes.

Fair Value

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of ~~June~~September 30, 2018 are as follows:


	Book Value of Long-Term Debt		Fair Value of Long-Term Debt (a) (b)		Book Value of Long-Term Debt		Fair Value of Long-Term Debt (a) (b)
	(In Thousands)				(In Thousands)
Entergy		$15,874,594		$15,521,205		$16,515,836		$16,232,180
Entergy Arkansas		$3,212,424		$2,991,503		$3,242,282		$3,031,681
Entergy Louisiana		$6,491,723		$6,406,225		$6,761,123		$6,757,649
Entergy Mississippi		$1,270,559		$1,240,643		$1,270,830		$1,234,124
Entergy New Orleans		$431,795		$441,342		$491,570		$499,764
Entergy Texas		$1,548,180		$1,581,882		$1,527,817		$1,546,101
System Energy		$601,662		$571,461		$639,455		$610,485


(a)	The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of ~~$185~~$186 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.

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Notes to Financial Statements

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.

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~~Notes to Financial Statements~~

NOTE 5. 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 ~~June~~September 30, 2018, there were options on ~~4,370,733~~4,071,301 shares of common stock outstanding with a weighted-average exercise price of ~~$74.40.~~$74.53. The intrinsic value, which has no effect on net income, of the outstanding stock options is calculated by the positive difference between the weighted average exercise price of the stock options granted and Entergy Corporation’s common stock price as of ~~June~~September 30, 2018. The aggregate intrinsic value of the stock options outstanding as of ~~June~~September 30, 2018 was ~~$27.9~~$26.9 million.

The following table includes financial information for outstanding stock options for the three months ended ~~June~~September 30, 2018 and 2017:



	2018		2017		2018		2017
	(In Millions)				(In Millions)
Compensation expense included in Entergy’s net income		$1.1		$1.1		$1.1		$1.1
Tax benefit recognized in Entergy’s net income		$0.3		$0.4		$0.2		$0.5
Compensation cost capitalized as part of fixed assets and inventory		$0.2		$0.2		$0.1		$0.2

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Notes to Financial Statements

The following table includes financial information for outstanding stock options for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017:


	2018		2017		2018		2017
	(In Millions)				(In Millions)
Compensation expense included in Entergy’s net income		$2.2		$2.2		$3.3		$3.3
Tax benefit recognized in Entergy’s net income		$0.6		$0.8		$0.8		$1.3
Compensation cost capitalized as part of fixed assets and inventory		$0.4		$0.4		$0.5		$0.6

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~~For the 2018-2020 performance period, a cumulative utility earnings metric ~~has been~~was 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.

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~~Notes to Financial Statements~~

The following table includes financial information for other outstanding equity awards for the three months ended ~~June~~September 30, 2018 and 2017:


	2018		2017		2018		2017
	(In Millions)				(In Millions)
Compensation expense included in Entergy’s net income		$8.7		$8.2		$8.5		$7.6
Tax benefit recognized in Entergy’s net income		$2.2		$3.2		$2.2		$3.0
Compensation cost capitalized as part of fixed assets and inventory		$2.5		$2.2		$2.5		$2.1

The following table includes financial information for other outstanding equity awards for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017:


	2018		2017		2018		2017
	(In Millions)				(In Millions)
Compensation expense included in Entergy’s net income		$17.5		$16.4		$26.0		$24.1
Tax benefit recognized in Entergy’s net income		$4.4		$6.3		$6.6		$9.3
Compensation cost capitalized as part of fixed assets and inventory		$4.8		$4.2		$7.3		$6.3

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Notes to Financial Statements

NOTE 6. 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 by Entergy 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 in other operation and maintenance expenses and decreases in other income for the three months ended September 30, 2017, with no change in net income, of $30 million for Entergy. The retroactive presentation changes resulted in decreases in other operation and maintenance expenses and decreases in other income for the nine months ended September 30, 2017, with no change in net income, of $76 million for Entergy.

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 ~~June~~September 30, 2017 and for the nine months ended September 30, 2017, with no change in net income, of $25 million for Entergy, $3.6 million for Entergy Arkansas, $6.2 million for Entergy Louisiana, $0.5 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, $14 thousand for Entergy Texas, and $2.3 million for System Energy. The retroactive presentation changes resulted in decreases (increases) in other operation and maintenance expenses and decreases (increases) in other incomethe following for the six months ended June 30, 2017, with no change in net income, of $46 million for Entergy, $6.4 million for Entergy Arkansas, $12.3 million for Entergy Louisiana, $1.1 million for Entergy Mississippi, $0.4 million for Entergy New Orleans, ($0.2) million for Entergy Texas, and $3.3 million for System Energy. Registrant Subsidiaries:



	Entergy Arkansas		Entergy Louisiana		Entergy Mississippi		Entergy New Orleans		Entergy Texas			System Energy
	(In Thousands)
Three months ended September 30, 2017		$3,515		$8,585		$778		$356		$43			$1,521
Nine months ended September 30, 2017		$9,995		$20,942		$1,862		$794		($194	)		$4,778

The retroactive effect of the change for the ~~year~~years ended December 31, 2017, 2016, and 2015 would be decreases in other operation and maintenance expenses and decreases in other income, with no change in net income, of ~~$108~~$101 million, $71 million, and $148 million, respectively, 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. Entergy.

The retroactive effect of the change for the ~~year~~years ended December 31, 2017, 2016, and 2015 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~~following 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~~Registrant Subsidiaries:



	Entergy Arkansas		Entergy Louisiana		Entergy Mississippi		Entergy New Orleans		Entergy Texas			System Energy
	(In Thousands)
For the Year Ended December 31, 2017		$13,668		$27,796		$2,742		$1,293		$179			$6,190
For the Year Ended December 31, 2016		$13,392		$26,118		$2,424		$1,014		($1,054	)		$5,088
For the Year Ended December 31, 2015		$30,671		$50,686		$6,268		$3,975		$4,000			$10,213

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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 ~~second~~third 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

Entergy’s qualified pension cost, including amounts capitalized, for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017, included the following components:


	2018			2017			2018			2017
	(In Thousands)						(In Thousands)
Service cost - benefits earned during the period		$77,504			$66,820			$116,256			$100,230
Interest cost on projected benefit obligation	133,708			130,412			200,562			195,618
Expected return on assets	(221,070		)	(204,112		)	(331,605		)	(306,168		)
Amortization of prior service cost	198			130			297			195
Amortization of loss	137,052			113,860			205,578			170,790
Net pension costs		$127,392			$107,110			$191,088			$160,665

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the ~~second~~third 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 projected 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

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Notes to Financial Statements

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

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017, included the following components:


2018	Entergy Arkansas			Entergy Louisiana			Entergy Mississippi			Entergy New Orleans			Entergy Texas			System Energy			Entergy Arkansas			Entergy Louisiana			Entergy Mississippi			Entergy New Orleans			Entergy Texas			System Energy
	(In Thousands)																		(In Thousands)
Service cost - benefits earned during the period		$12,378			$16,892			$3,644			$1,346			$3,178			$3,552			$18,567			$25,338			$5,466			$2,019			$4,767			$5,328
Interest cost on projects benefit obligation	26,008			29,880			7,538			3,626			6,696			6,454			39,012			44,820			11,307			5,439			10,044			9,681
Expected return on assets	(43,702		)	(49,618		)	(13,004		)	(5,986		)	(13,046		)	(9,982		)	(65,553		)	(74,427		)	(19,506		)	(8,979		)	(19,569		)	(14,973		)
Amortization of loss	26,824			28,900			7,220			3,908			5,252			7,430			40,236			43,350			10,830			5,862			7,878			11,145
Net pension cost		$21,508			$26,054			$5,398			$2,894			$2,080			$7,454			$32,262			$39,081			$8,097			$4,341			$3,120			$11,181


2017	Entergy Arkansas			Entergy Louisiana			Entergy Mississippi			Entergy New Orleans			Entergy Texas			System Energy			Entergy Arkansas			Entergy Louisiana			Entergy Mississippi			Entergy New Orleans			Entergy Texas			System Energy
	(In Thousands)																		(In Thousands)
Service cost - benefits earned during the period		$10,180			$13,850			$2,944			$1,250			$2,728			$3,072			$15,270			$20,775			$4,416			$1,875			$4,092			$4,608
Interest cost on projected benefit obligation	25,888			29,618			7,464			3,582			6,784			6,182			38,832			44,427			11,196			5,373			10,176			9,273
Expected return on assets	(40,854		)	(46,034		)	(12,262		)	(5,600		)	(12,360		)	(9,326		)	(61,281		)	(69,051		)	(18,393		)	(8,400		)	(18,540		)	(13,989		)
Amortization of loss	23,280			24,708			6,106			3,316			4,620			5,928			34,920			37,062			9,159			4,974			6,930			8,892
Net pension cost		$18,494			$22,142			$4,252			$2,548			$1,772			$5,856			$27,741			$33,213			$6,378			$3,822			$2,658			$8,784

Non-Qualified Net Pension Cost

Entergy recognized ~~$6.6~~$4.2 million and ~~$8.5~~$15.8 million in pension cost for its non-qualified pension plans in the ~~second~~third quarters of 2018 and 2017, respectively. Reflected in the pension cost for non-qualified pension plans in the ~~second~~third quarters of 2018 and 2017 were settlement charges of ~~$2.4 million~~$212 thousand and $4$11.6 million, respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized ~~$15.5~~$19.7 million and ~~$13.1~~$28.9 million in pension cost for its non-qualified pension plans for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017, respectively. Reflected in the pension cost for non-qualified pension plans for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017 were settlement charges of ~~$6.8~~$7 million and $4$15.5 million, respectively, related to the payment of lump sum benefits out of this plan.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2018 and 2017:



	Entergy Arkansas		Entergy Louisiana		Entergy Mississippi		Entergy New Orleans		Entergy Texas
	(In Thousands)
2018		$114		$42		$73		$20		$122
2017		$111		$46		$62		$18		$124

Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarters of 2018 and 2017, were settlement charges of $7 thousand and $10 thousand, respectively, related to the payment of lump sum benefits out of the plan.

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The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the ~~second quarters of 2018 and 2017:~~

Entergy
Arkansas

Entergy
Louisiana

Entergy
Mississippi

Entergy
New Orleans

Entergy
Texas
(In Thousands)
2018
$122

$46

$77

$21

$270
2017
$267

$47

$63

$18

$126

Reflected in Entergy Arkansas’s non-qualified pension costs in the second quarters of 2018 and 2017, were settlement charges of $10 thousand and $163 thousand, respectively, related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs in the second quarter of 2018 were settlement charges of $139 thousand 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 six~~nine months ended ~~June~~September 30, 2018 and 2017:


	Entergy Arkansas		Entergy Louisiana		Entergy Mississippi		Entergy New Orleans		Entergy Texas		Entergy Arkansas		Entergy Louisiana		Entergy Mississippi		Entergy New Orleans		Entergy Texas
	(In Thousands)										(In Thousands)
2018		$254		$96		$157		$42		$407		$369		$138		$230		$62		$529
2017		$372		$96		$127		$36		$253		$483		$141		$189		$55		$377

Reflected in Entergy Arkansas’s non-qualified pension costs for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017, were settlement charges of ~~$22~~$30 thousand and ~~$163~~$173 thousand, respectively, related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the ~~six~~nine months ended ~~June~~September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefit Cost

Entergy’s other postretirement benefit cost, including amounts capitalized, for the ~~second~~third 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

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~~Notes to Financial Statements~~

Entergy’s other postretirement benefit cost, including amounts capitalized, for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017, included the following components:

2018 2017
(In Thousands)
Service cost - benefits earned during the period
$13,564

$13,458
Interest cost on accumulated postretirement benefit obligation (APBO) 25,362
27,920
Expected return on assets (20,746 ) (18,816 )
Amortization of prior service credit (18,502 ) (20,712 )
Amortization of loss 6,864
10,952
Net other postretirement benefit cost
$6,542

$12,802

~~The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the second 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
																			2018			2017
	(In Thousands)																		(In Thousands)
Service cost - benefits earned during the period		$863			$1,593			$290			$142			$372			$320			$20,346			$20,187
Interest cost on APBO	2,255			3,025			690			469			1,124			559
Interest cost on accumulated postretirement benefit obligation (APBO)																			38,043			41,880
Expected return on assets	(3,959		)	—			(1,200		)	(1,159		)	(2,180		)	(717		)	(31,119		)	(28,224		)
Amortization of prior service credit	(1,278		)	(1,934		)	(456		)	(186		)	(579		)	(378		)	(27,753		)	(31,068		)
Amortization of loss	1,115			465			419			105			826			390			10,296			16,428
Net other postretirement benefit cost		($1,004	)		$3,149			($257	)		($629	)		($437	)		$174			$9,813			$19,203

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The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the ~~six~~third 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

The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended ~~June~~September 30, 2018 and 2017, included the following components:


2018	Entergy Arkansas			Entergy Louisiana			Entergy Mississippi			Entergy New Orleans			Entergy Texas			System Energy			Entergy Arkansas			Entergy Louisiana			Entergy Mississippi			Entergy New Orleans			Entergy Texas			System Energy
	(In Thousands)																		(In Thousands)
Service cost - benefits earned during the period		$1,586			$3,112			$642			$258			$660			$612			$2,379			$4,668			$963			$387			$990			$918
Interest cost on APBO	3,994			5,578			1,366			834			1,878			1,000			5,991			8,367			2,049			1,251			2,817			1,500
Expected return on assets	(8,684		)	—			(2,606		)	(2,626		)	(4,892		)	(1,566		)	(13,026		)	—			(3,909		)	(3,939		)	(7,338		)	(2,349		)
Amortization of prior service credit	(2,556		)	(3,868		)	(912		)	(372		)	(1,158		)	(756		)	(3,834		)	(5,802		)	(1,368		)	(558		)	(1,737		)	(1,134		)
Amortization of loss	578			776			754			68			412			466			867			1,164			1,131			102			618			699
Net other postretirement benefit cost		($5,082	)		$5,598			($756	)		($1,838	)		($3,100	)		($244	)		($7,623	)		$8,397			($1,134	)		($2,757	)		($4,650	)		($366	)

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Entergy Corporation and Subsidiaries

Notes to Financial Statements


2017	Entergy Arkansas			Entergy Louisiana			Entergy Mississippi			Entergy New Orleans			Entergy Texas			System Energy			Entergy Arkansas			Entergy Louisiana			Entergy Mississippi			Entergy New Orleans			Entergy Texas			System Energy
	(In Thousands)																		(In Thousands)
Service cost - benefits earned during the period		$1,726			$3,186			$580			$284			$744			$640			$2,589			$4,779			$870			$426			$1,116			$960
Interest cost on APBO	4,510			6,050			1,380			938			2,248			1,118			6,765			9,075			2,070			1,407			3,372			1,677
Expected return on assets	(7,918		)	—			(2,400		)	(2,318		)	(4,360		)	(1,434		)	(11,877		)	—			(3,600		)	(3,477		)	(6,540		)	(2,151		)
Amortization of prior service credit	(2,556		)	(3,868		)	(912		)	(372		)	(1,158		)	(756		)	(3,834		)	(5,802		)	(1,368		)	(558		)	(1,737		)	(1,134		)
Amortization of loss	2,230			930			838			210			1,652			780			3,345			1,395			1,257			315			2,478			1,170
Net other postretirement benefit cost		($2,008	)		$6,298			($514	)		($1,258	)		($874	)		$348			($3,012	)		$9,447			($771	)		($1,887	)		($1,311	)		$522

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the ~~second~~third quarters of 2018 and 2017:


2018	Qualified Pension Costs			Other Postretirement Costs			Non-Qualified Pension Costs			Total			Qualified Pension Costs			Other Postretirement Costs			Non-Qualified Pension Costs			Total
	(In Thousands)												(In Thousands)
Entergy
Amortization of prior service (cost)/credit		($99	)		$5,594			($71	)		$5,424			($99	)		$5,595			($71	)		$5,425
Amortization of loss	(21,957		)	(1,933		)	(918		)	(24,808		)	(21,958		)	(1,932		)	(850		)	(24,740		)
Settlement loss	—			—			(406		)	(406		)	—			—			(76		)	(76		)
		($22,056	)		$3,661			($1,395	)		($19,790	)		($22,057	)		$3,663			($997	)		($19,391	)
Entergy Louisiana
Amortization of prior service credit		$—			$1,934			$—			$1,934			$—			$1,934			$—			$1,934
Amortization of loss	(867		)	(387		)	(2		)	(1,256		)	(867		)	(388		)	(2		)	(1,257		)
		($867	)		$1,547			($2	)		$678			($867	)		$1,546			($2	)		$677



2017	Qualified Pension Costs			Other Postretirement Costs			Non-Qualified Pension Costs			Total
	(In Thousands)
Entergy
Amortization of prior service (cost)/credit		($65	)		$6,718			($88	)		$6,565
Amortization of loss	(18,451		)	(2,202		)	(827		)	(21,480		)
Settlement loss	—			—			(4,200		)	(4,200		)
		($18,516	)		$4,516			($5,115	)		($19,115	)
Entergy Louisiana
Amortization of prior service credit		$—			$1,934			$—			$1,934
Amortization of loss	(865		)	(465		)	(2		)	(1,332		)
		($865	)		$1,469			($2	)		$602

5965

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

2017
Qualified
Pension
Costs
Other
Postretirement
Costs
Non-Qualified
Pension Costs
Total

(In Thousands)

Entergy

Amortization of prior service (cost)/credit

($65 )

$6,718

($89 )

$6,564
Amortization of loss
(18,450 )
(2,202 )
(902 )
(21,554 )
Settlement loss
—

—

(1,765 )
(1,765 )

($18,515 )

$4,516

($2,756 )

($16,755 )
Entergy Louisiana

Amortization of prior service credit

$—

$1,934

$—

$1,934
Amortization of loss
(865 )
(465 )
(2 )
(1,332 )

($865 )

$1,469

($2 )

$602


2018	Qualified Pension Costs			Other Postretirement Costs			Non-Qualified Pension Costs			Total			Qualified Pension Costs			Other Postretirement Costs			Non-Qualified Pension Costs			Total
	(In Thousands)												(In Thousands)
Entergy
Amortization of prior service (cost)/credit		($198	)		$11,189			($141	)		$10,850			($297	)		$16,786			($211	)		$16,278
Amortization of loss	(43,914		)	(3,865		)	(1,981		)	(49,760		)	(65,870		)	(5,801		)	(2,832		)	(74,503		)
Settlement loss	—			—			(2,022		)	(2,022		)	—			—			(2,098		)	(2,098		)
		($44,112	)		$7,324			($4,144	)		($40,932	)		($66,167	)		$10,985			($5,141	)		($60,323	)
Entergy Louisiana
Amortization of prior service credit		$—			$3,868			$—			$3,868			$—			$5,802			$—			$5,802
Amortization of loss	(1,734		)	(775		)	(4		)	(2,513		)	(2,601		)	(1,164		)	(5		)	(3,770		)
		($1,734	)		$3,093			($4	)		$1,355			($2,601	)		$4,638			($5	)		$2,032

2017 Qualified
Pension
Costs Other
Postretirement
Costs Non-Qualified
Pension Costs Total
(In Thousands)
Entergy
Amortization of prior service (cost)/credit
($130 )
$13,435

($179 )
$13,126
Amortization of loss (36,899 ) (4,404 ) (1,822 ) (43,125 )
Settlement loss —
—
(1,765 ) (1,765 )

($37,029 )
$9,031

($3,766 )
($31,764 )
Entergy Louisiana
Amortization of prior service credit
$—

$3,868

$—

$3,868
Amortization of loss (1,730 ) (930 ) (4 ) (2,664 )

($1,730 )
$2,938

($4 )
$1,204

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~~Entergy Corporation and Subsidiaries~~

~~Notes to Financial Statements~~



2017	Qualified Pension Costs			Other Postretirement Costs			Non-Qualified Pension Costs			Total
	(In Thousands)
Entergy
Amortization of prior service (cost)/credit		($195	)		$20,152			($266	)		$19,691
Amortization of loss	(55,351		)	(6,606		)	(2,648		)	(64,605		)
Settlement loss	—			—			(5,965		)	(5,965		)
		($55,546	)		$13,546			($8,879	)		($50,879	)
Entergy Louisiana
Amortization of prior service credit		$—			$5,802			$—			$5,802
Amortization of loss	(2,594		)	(1,395		)	(7		)	(3,996		)
		($2,594	)		$4,407			($7	)		$1,806

Employer Contributions

Based on current assumptions, Entergy expects to contribute ~~$352.1~~$383.5 million to its qualified pension plans in 2018. As of ~~June~~September 30, 2018, Entergy had contributed ~~$159.7~~$315.6 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2018:


	Entergy Arkansas		Entergy Louisiana		Entergy Mississippi		Entergy New Orleans		Entergy Texas		System Energy		Entergy Arkansas		Entergy Louisiana		Entergy Mississippi		Entergy New Orleans		Entergy Texas		System Energy
	(In Thousands)												(In Thousands)
Expected 2018 pension contributions		$64,062		$71,917		$14,933		$7,250		$10,883		$13,786		$64,062		$71,919		$14,933		$7,250		$10,883		$13,786
Pension contributions made through June 2018		$29,453		$33,066		$6,924		$3,373		$5,433		$6,349
Pension contributions made through September 2018														$51,982		$58,363		$12,203		$5,938		$9,323		$11,152
Remaining estimated pension contributions to be made in 2018		$34,609		$38,851		$8,009		$3,877		$5,450		$7,437		$12,080		$13,556		$2,730		$1,312		$1,560		$2,634

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

NOTE 7. BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy Corporation

Entergy’s reportable segments as of ~~June~~September 30, 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 ~~second~~third quarters of 2018 and 2017 is as follows:

Utility
Entergy
Wholesale
Commodities
All Other Eliminations Entergy
(In Thousands)
2018
Operating revenues
$2,360,208

$308,602

$—

($40 )
$2,668,770
Income taxes
($240,324 )
($30,144 )
($10,128 )
$—

($280,596 )
Consolidated net income (loss)
$378,394

($56,337 )
($41,299 )
($31,898 )
$248,860
2017
Operating revenues
$2,301,332

$317,255

$—

($37 )
$2,618,550
Income taxes
$130,851

($454,944 )
($13,019 )
$—

($337,112 )
Consolidated net income (loss)
$246,382

$223,886

($25,001 )
($31,899 )
$413,368

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~~Entergy Corporation and Subsidiaries~~

~~Notes to Financial Statements~~



	Utility			Entergy Wholesale Commodities			All Other			Eliminations			Entergy
	(In Thousands)
2018
Operating revenues		$2,724,279			$380,080			$—			($40	)		$3,104,319
Income taxes		($137,035	)		($135,659	)		($10,312	)		$—			($283,006	)
Consolidated net income (loss)		$507,745			$105,571			($41,601	)		($31,897	)		$539,818
2017
Operating revenues		$2,820,421			$423,245			$—			($38	)		$3,243,628
Income taxes		$230,647			$25,563			($14,415	)		$—			$241,795
Consolidated net income (loss)		$403,733			$55,765			($25,956	)		($31,898	)		$401,644

Entergy’s segment financial information for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017 is as follows:


	Utility			Entergy Wholesale Commodities			All Other			Eliminations			Entergy			Utility			Entergy Wholesale Commodities			All Other			Eliminations			Entergy
	(In Thousands)															(In Thousands)
2018
Operating revenues		$4,665,197			$727,526			$—			($73	)		$5,392,650			$7,389,477			$1,107,606			$—			($113	)		$8,496,970
Income taxes		($188,100	)		($31,222	)		($17,611	)		$—			($236,933	)		($325,134	)		($166,882	)		($27,921	)		$—			($519,937	)
Consolidated net income (loss)		$596,333			($74,116	)		($73,361	)		($63,797	)		$385,059			$1,104,078			$31,456			($114,962	)		($95,695	)		$924,877
Total assets as of June 30, 2018		$44,117,784			$5,433,618			$1,240,106			($3,168,859	)		$47,622,649
Total assets as of September 30, 2018																	$44,889,498			$5,507,013			$1,274,909			($3,200,248	)		$48,471,172
2017
Operating revenues	$4,336,444			$870,622				$—		($58)			$5,207,008				$7,156,865			$1,293,867			$—			($96	)		$8,450,636
Income taxes	$229,343			($533,281)			($25,412)				$—		($329,350)				$459,990			($507,719	)		($39,826	)		$—			($87,555	)
Consolidated net income (loss)		$414,005			$196,689			($47,477	)		($63,797	)		$499,420			$817,738			$252,455			($73,434	)		($95,695	)		$901,064
Total assets as of December 31, 2017	$42,978,669			$5,638,009			$1,011,612			($2,921,141)			$46,707,149				$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.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

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 ~~second~~third quarters of 2018 and 2017 were comprised of the following:

2018 2017

Employee retention and severance
expenses and other benefits-related costs
Contracted economic development costs Total Employee retention and severance
expenses and other benefits-related costs Contracted economic development costs Total
(In Millions)
Balance as of April 1,
$109

$14

$123

$94

$21

$115
Restructuring costs accrued 34
—
34
42
—
42
Cash paid out —
—
—
100
—
100
Balance as of June 30,
$143

$14

$157

$36

$21

$57



	2018						2017
	Employee retention and severance expenses and other benefits-related costs		Contracted economic development costs		Total		Employee retention and severance expenses and other benefits-related costs		Contracted economic development costs			Total
	(In Millions)
Balance as of July 1,		$143		$14		$157		$36		$21			$57
Restructuring costs accrued	43		—		43		23		—			23
Non-cash portion	—		—		—		—		(7		)	(7		)
Balance as of September 30,		$186		$14		$200		$59		$14			$73

In addition, Entergy incurred ~~$69~~$155 million in the ~~second~~third quarter 2018 and ~~$194~~$16 million in the ~~second~~third 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.

~~Table of Contents~~

~~Entergy Corporation and Subsidiaries~~

~~Notes to Financial Statements~~

Total restructuring charges for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017 were comprised of the following:


	2018						2017						2018						2017
	Employee retention and severance expenses and other benefits-related costs		Contracted economic development costs		Total		Employee retention and severance expenses and other benefits-related costs		Contracted economic development costs		Total		Employee retention and severance expenses and other benefits-related costs		Contracted economic development costs		Total		Employee retention and severance expenses and other benefits-related costs		Contracted economic development costs			Total
	(In Millions)												(In Millions)
Balance as of January 1,		$83		$14		$97		$70		$21		$91		$83		$14		$97		$70		$21			$91
Restructuring costs accrued	60		—		60		66		—		66		103		—		103		89		—			89
Non-cash portion													—		—		—		—		(7		)	(7		)
Cash paid out	—		—		—		100		—		100		—		—		—		100		—			100
Balance as of June 30,		$143		$14		$157		$36		$21		$57
Balance as of September 30,														$186		$14		$200		$59		$14			$73

In addition, Entergy incurred ~~$142~~$297 million in the ~~six~~nine months ended ~~June~~September 30, 2018 and ~~$405~~$422 million in the ~~six~~nine months ended ~~June~~September 30, 2017 of impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

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 $155 million in 2018, of which ~~$60~~$103 million has been incurred as of ~~June~~September 30, 2018, and a total of approximately $215 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.

NOTE 8. 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.

~~Table of Contents~~

~~Entergy Corporation and Subsidiaries~~

~~Notes to Financial Statements~~

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

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

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 ~~June~~September 30, 2018 is approximately 2.5 years. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2018, of which approximately ~~82%~~87% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts. Total planned generation for the remainder of 2018 is ~~14.1~~6.7 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 ~~June~~September 30, 2018, derivative contracts with seven counterparties were in a liability position (approximately ~~$30~~$68 million total). In addition to the corporate guarantee, $5$30 million in cash collateral was required

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~~Notes to Financial Statements~~

to be posted by the Entergy subsidiary to its ~~counterparties and $3 million in cash collateral and $3 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary.~~counterparties. 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 ~~June~~September 30, 2018 is ~~39,670,000~~13,814,000 MMBtu for Entergy, including ~~32,100,000~~6,300,000 MMBtu for Entergy Louisiana, ~~and 7,570,000~~6,790,000 MMBtu for Entergy ~~Mississippi.~~Mississippi, and 724,000 MMBtu for Entergy New Orleans. 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 2018, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2018 through May 31, 2019. 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

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accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of ~~June~~September 30, 2018 is ~~108,294~~77,520 GWh for Entergy, including ~~24,646~~17,557 GWh for Entergy Arkansas, ~~46,135~~33,144 GWh for Entergy Louisiana, ~~14,368~~10,295 GWh for Entergy Mississippi, ~~5,184~~3,758 GWh for Entergy New Orleans, and ~~17,512~~12,441 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of ~~June~~September 30, 2018 and December 31, 2017. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, ~~and Entergy Mississippi as of June 30, 2018 and Entergy Arkansas,~~ Entergy Mississippi, and Entergy Texas as of September 30, 2018 and December 31, ~~2017.~~2017, respectively.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of ~~June~~September 30, 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.

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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)	$10	($10)	$—	Entergy Wholesale Commodities
Electricity swaps and options	Other deferred debits and other assets (non-current portion)	$10	($10)	$—	Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options	Other current liabilities (current portion)	$62	($10)	$52	Entergy Wholesale Commodities
Electricity swaps and options	Other non-current liabilities (non-current portion)	$24	($11)	$13	Entergy Wholesale Commodities
Derivatives not designated as hedging instruments
Assets:
Electricity swaps and options	Prepayments and other (current portion)	$3	($3)	$—	Entergy Wholesale Commodities
Natural gas swaps	Prepayments and other	$1	$—	$1	Utility
Financial transmission rights	Prepayments and other	$31	($2)	$29	Utility and Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options	Other current liabilities (current portion)	$4	($3)	$1	Entergy Wholesale Commodities
Electricity swaps and options	Other non-current liabilities (non-current portion)	$1	$—	$1	Entergy Wholesale Commodities

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) $29 ($21) $8 Entergy Wholesale Commodities
Electricity swaps and options Other deferred debits and other assets (non-current portion) $11 ($11) $— Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options Other current liabilities
(current portion) $34 ($21) $13 Entergy Wholesale Commodities
Electricity swaps and options Other non-current liabilities (non-current portion) $30 ($10) $20 Entergy Wholesale Commodities
Derivatives not designated as hedging instruments
Assets:
Electricity swaps and options Prepayments and other (current portion) $2 ($2) $— Entergy Wholesale Commodities
Natural gas swaps Prepayments and other $3 $— $3 Utility
Financial transmission rights Prepayments and other $42 $1 $41 Utility and Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options Other current liabilities
(current portion) $2 ($2) $— Entergy Wholesale Commodities

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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 $5$30 million posted ~~and $3 million held~~ as of ~~June~~September 30, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes letters of credit in the amount of $1$5 million posted ~~and $3 million held~~ as of ~~June~~September 30, 2018 and $34 million in letters of credit held as of December 31, 2017.

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The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended ~~June~~September 30, 2018 and 2017 are as follows:

Instrument

Amount of gain (loss)

recognized in other

comprehensive income

Income Statement location

Amount of gain

reclassified from

accumulated other comprehensive income into income (a)

Amount of gain (loss)

recognized in other

comprehensive income

Income Statement location

Amount of gain (loss)

reclassified from

accumulated other comprehensive income into income (a)

(In Millions)

2018

Electricity swaps and options

($80)

Competitive businesses operating revenues

($51)

Competitive businesses operating revenues

($11)

2017

Electricity swaps and options

$43

Competitive businesses operating revenues

$13

$43

Competitive businesses operating revenues

$23


(a)	Before taxes of $1($2) million and $4$8 million for the three months ended ~~June~~September 30, 2018 and 2017, respectively

The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017 are as follows:

Instrument

Amount of gain recognized in other
comprehensive income

Income Statement location

Amount of gain (loss)
reclassified from
accumulated other comprehensive income into income (a)

Amount of gain (loss) recognized in other
comprehensive income

Income Statement location

Amount of gain (loss)
reclassified from
accumulated other comprehensive income into income (a)

(In Millions)

2018

Electricity swaps and options

$11

Competitive businesses operating revenues

($27)

($40)

Competitive businesses operating revenues

($38)

2017

Electricity swaps and options

$93

Competitive businesses operating revenues

$64

$136

Competitive businesses operating revenues

$87


(a)	Before taxes of ($6)8) million and ~~$22~~$30 million for the ~~six~~nine months ended ~~June~~September 30, 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 ~~June~~September 30, 2018 and 2017 was ($~~15)~~3.1) million and $5$2.4 million, respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017 was ($2)5.2) million and $4$6.4 million, respectively.

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Based on market prices as of ~~June~~September 30, 2018, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled ($~~17)~~58) million of net unrealized losses. Approximately ($2)47) million is expected to be reclassified from accumulated other comprehensive income to

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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 ~~June~~September 30, 2018 and 2017 are as follows:



Instrument	Amount of ~~loss~~gain (loss) recognized in accumulated other comprehensive income		Income Statement location		Amount of gain (loss) recorded in the income statement
	(In Millions)				(In Millions)
2018
Natural gas swaps	$—		Fuel, fuel-related expenses, and gas purchased for resale	(a)	$6—
Financial transmission rights	$—		Purchased power expense	(b)	$4131
Electricity swaps and options	$—	(c)	Competitive business operating revenues		$1($2)

2017
Natural gas swaps	$—		Fuel, fuel-related expenses, and gas purchased for resale	(a)	($9)3)
Financial transmission rights	$—		Purchased power expense	(b)	$4428
Electricity swaps and options	($5)2)	(c)	Competitive business operating revenues		$—

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The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017 are as follows:



Instrument	Amount of gain (loss) recognized in accumulated other comprehensive income		Income Statement location		Amount of gain (loss) recorded in the income statement
	(In Millions)				(In Millions)
2018
Natural gas swaps	$—		Fuel, fuel-related expenses, and gas purchased for resale	(a)	$65
Financial transmission rights	$—		Purchased power expense	(b)	$73104
Electricity swaps and options	$—	(c)	Competitive business operating revenues		$1—

2017
Natural gas swaps	$—		Fuel, fuel-related expenses, and gas purchased for resale	(a)	($~~16)~~20)
Financial transmission rights	$—		Purchased power expense	(b)	$75103
Electricity swaps and options	$42	(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.

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The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of ~~June~~September 30, 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	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)					(In Millions)
Assets:
Natural gas swaps	Prepayments and other	$2.7	$—	$2.7	Entergy Louisiana	Prepayments and other	$1.0	$—	$1.0	Entergy Louisiana
Natural gas swaps	Prepayments and other	$0.5	$—	$0.5	Entergy Mississippi	Prepayments and other	$0.4	$—	$0.4	Entergy Mississippi

Financial transmission rights	Prepayments and other	$11.1	($0.6)	$10.5	Entergy Arkansas	Prepayments and other	$11.6	($0.3)	$11.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$18.5	($0.3)	$18.2	Entergy Louisiana	Prepayments and other	$12.2	($0.2)	$12.0	Entergy Louisiana
Financial transmission rights	Prepayments and other	$4.4	$—	$4.4	Entergy Mississippi	Prepayments and other	$3.7	$—	$3.7	Entergy Mississippi
Financial transmission rights	Prepayments and other	$3.0	$—	$3.0	Entergy New Orleans	Prepayments and other	$2.1	$—	$2.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$5.3	($0.6)	$4.7	Entergy Texas	Prepayments and other	$1.7	($1.6)	$0.1	Entergy Texas

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 ~~June~~September 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of ~~$0.6~~$1 million for Entergy Arkansas, ~~and~~ $0.2 million for Entergy ~~Mississippi. As of December 31, 2017, letters of~~Mississippi, and $3.6 million for Entergy Texas.

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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 ~~June~~September 30, 2018 and 2017 are as follows:



Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
2018
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	~~$4.9~~($0.7)	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$~~0.9~~0.1	(a)	Entergy Mississippi

Financial transmission rights	Purchased power expense	$~~2.1~~10.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$~~25.8~~13.8	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$~~9.8~~5.4	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$~~5.2~~2.0	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	($~~1.8)~~0.4)	(b)	Entergy Texas

2017
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($~~7.6)~~2.6)	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($~~1.4)~~0.6)	(a)	Entergy Mississippi

Financial transmission rights	Purchased power expense	$~~10.5~~4.2	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$~~14.3~~9.4	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$~~8.5~~4.7	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$~~3.4~~1.9	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$~~6.9~~7.0	(b)	Entergy Texas

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The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017 are as follows:



Instrument	Income Statement Location	Amount of gain (loss) recorded in the income statement		Registrant
		(In Millions)
2018
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$~~4.9~~4.2	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	$~~0.7~~0.9	(a)	Entergy Mississippi

Financial transmission rights	Purchased power expense	$20.1	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$57.2	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$23.0	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$10.5	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	($5.6)	(b)	Entergy Texas

2017
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($16.3)	(a)	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($3.1)	(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	$~~10.1~~19.3	(b)	Entergy Arkansas
Financial transmission rights	Purchased power expense	$~~43.4~~38.9	(b)	Entergy Louisiana
Financial transmission rights	Purchased power expense	$~~17.6~~16.3	(b)	Entergy Mississippi
Financial transmission rights	Purchased power expense	$~~8.4~~	~~(b)~~	~~Entergy New Orleans~~
~~Financial transmission rights~~	~~Purchased power expense~~	~~($5.3)~~	~~(b)~~	~~Entergy Texas~~

~~2017~~
~~Natural gas swaps~~	~~Fuel, fuel-related expenses, and gas purchased for resale~~	~~($13.7)~~	~~(a)~~	~~Entergy Louisiana~~
~~Natural gas swaps~~	~~Fuel, fuel-related expenses, and gas purchased for resale~~	~~($2.5)~~	~~(a)~~	~~Entergy Mississippi~~
~~Natural gas swaps~~	~~Fuel, fuel-related expenses, and gas purchased for resale~~	~~($0.1)~~	~~(a)~~	~~Entergy New Orleans~~

~~Financial transmission rights~~	~~Purchased power expense~~	~~$15.1~~	~~(b)~~	~~Entergy Arkansas~~
~~Financial transmission rights~~	~~Purchased power expense~~	~~$29.5~~	~~(b)~~	~~Entergy Louisiana~~
~~Financial transmission rights~~	~~Purchased power expense~~	~~$11.6~~	~~(b)~~	~~Entergy Mississippi~~
~~Financial transmission rights~~	~~Purchased power expense~~	~~$5.7~~7.7	(b)	Entergy New Orleans
Financial transmission rights	Purchased power expense	$~~12.1~~19.2	(b)	Entergy Texas


(a)	Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)

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

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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

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

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.

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Notes to Financial Statements

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of ~~June~~September 30, 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		Level 1		Level 2		Level 3		Total
	(In Millions)								(In Millions)
Assets:
Temporary cash investments		$758		$—		$—		$758		$923		$—		$—		$923
Decommissioning trust funds (a):
Equity securities	562		—		—		562		1,569		—		—		1,569
Debt securities	1,064		1,556		—		2,620		1,167		1,678		—		2,845
Common trusts (b)							4,035								3,030
Power contracts	—		—		8		8
Securitization recovery trust account	40		—		—		40		58		—		—		58
Escrow accounts	399		—		—		399		401		—		—		401
Gas hedge contracts	3		—		—		3		1		—		—		1
Financial transmission rights	—		—		41		41		—		—		29		29
		$2,826		$1,556		$49		$8,466		$4,119		$1,678		$29		$8,856

Liabilities:
Power contracts		$—		$—		$33		$33		$—		$—		$67		$67



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.

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Notes to Financial Statements

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended ~~June~~September 30, 2018 and 2017:


	2018						2017						2018						2017
	Power Contracts			Financial transmission rights			Power Contracts			Financial transmission rights			Power Contracts			Financial transmission rights			Power Contracts			Financial transmission rights
	(In Millions)												(In Millions)
Balance as of April 1,		$75			$8			$5			$8
Balance as of July 1,														($25	)		$41			$38			$57
Total gains (losses) for the period (a)
Included in earnings	(15		)	—			4			—			(4		)	—			2			—
Included in other comprehensive income	(80		)	—			43			—			(51		)	—			43			—
Included as a regulatory liability/asset	—			28			—			31			—			19			—			8
Issuances of financial transmission rights	—			46			—			62
Settlements	(5		)	(41		)	(14		)	(44		)	13			(31		)	(23		)	(28		)
Balance as of June 30,		($25	)		$41			$38			$57
Balance as of September 30,														($67	)		$29			$60			$37


(a)	Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ~~($0.8)~~$1.7 million for the three months ended ~~June~~September 30, 2018 and ~~($0.1)~~$0.4 million for the three months ended ~~June~~September 30, 2017.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017:


	2018						2017						2018						2017
	Power Contracts			Financial transmission rights			Power Contracts			Financial transmission rights			Power Contracts			Financial transmission rights			Power Contracts			Financial transmission rights
	(In Millions)												(In Millions)
Balance as of January 1,		($65	)		$21			$5			$21			($65	)		$21			$5			$21
Total gains (losses) for the period (a)
Included in earnings	(1		)	(1		)	4			—			(5		)	(1		)	6			1
Included in other comprehensive income	11			—			93			—			(40		)	—			136			—
Included as a regulatory liability/asset	—			48			—			48			—			67			—			56
Issuances of financial transmission rights	—			46			—			62			—			46			—			62
Settlements	30			(73		)	(64		)	(74		)	43			(104		)	(87		)	(103		)
Balance as of June 30,		($25	)		$41			$38			$57
Balance as of September 30,														($67	)		$29			$60			$37


(a)	Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ~~($0.7)~~$1.1 million for the ~~six~~nine months ended ~~June~~September 30, 2018 and ~~$0.3~~$1 million for the ~~six~~nine months ended ~~June~~September 30, 2017.

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Notes to Financial Statements

The following table sets forth a description of the types of transactions classified as Level 3 in the fair value hierarchy and significant unobservable inputs to each which cause that classification as of ~~June~~September 30, 2018:

Transaction Type
Fair Value
as of
June 30, 2018

Significant
Unobservable Inputs

Range
from
Average
%

Effect on
Fair Value
(In Millions) (In Millions)
Power contracts - electricity swaps ($25) Unit contingent discount +/- 4% - 4.75% ($3)



Transaction Type	Fair Value as of September 30, 2018	Significant Unobservable Inputs	Range from Average %		Effect on Fair Value
	(In Millions)				(In Millions)
Power contracts - electricity swaps	($67)	Unit contingent discount	+/-	4% - 4.75%	($6) - ($7)

The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs:



Significant Unobservable Input	Transaction Type	Position	Change to Input	Effect on Fair Value
Unit contingent discount	Electricity swaps	Sell	Increase (Decrease)	Decrease (Increase)

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of ~~June~~September 30, 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.

Entergy Arkansas


2018	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
	(In Millions)								(In Millions)
Assets:
Temporary cash investments		$232.8		$—		$—		$232.8		$208.7		$—		$—		$208.7
Decommissioning trust funds (a):
Equity securities		$11.3		$—		$—		$11.3	2.2		—		—		2.2
Debt securities	89.1		252.6		—		341.7		111.0		267.5		—		378.5
Common trusts (b)							601.4								616.2
Securitization recovery trust account	4.1		—		—		4.1		8.6		—		—		8.6
Financial transmission rights	—		—		10.5		10.5		—		—		11.3		11.3
		$337.3		$252.6		$10.5		$1,201.8		$330.5		$267.5		$11.3		$1,225.5



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

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Notes to Financial Statements

Entergy Louisiana


2018	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
	(In Millions)								(In Millions)
Assets:
Temporary cash investments		$28.8		$—		$—		$28.8		$213.2		$—		$—		$213.2
Decommissioning trust funds (a):
Equity securities	18.1		—		—		18.1		12.9		—		—		12.9
Debt securities	141.5		372.3		—		513.8		157.9		362.6		—		520.5
Common trusts (b)							803.0								861.8
Escrow accounts	286.7		—		—		286.7		288.1		—		—		288.1
Securitization recovery trust account	3.4		—		—		3.4		10.0		—		—		10.0
Gas hedge contracts	2.7		—		—		2.7		1.0		—		—		1.0
Financial transmission rights	—		—		18.2		18.2		—		—		12.0		12.0
		$481.2		$372.3		$18.2		$1,674.7		$683.1		$362.6		$12.0		$1,919.5


2017	Level 1			Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
	(In Millions)									(In Millions)
Assets:			��
Temporary cash investments		$30.1			$—		$—		$30.1		$30.1		$—		$—		$30.1
Decommissioning trust funds (a):
Equity securities	15.2			—		—		15.2		15.2		—		—		15.2
Debt securities	143.3			350.5		—		493.8		143.3		350.5		—		493.8
Common trusts (b)								803.1								803.1
Escrow accounts	289.5			—		—		289.5		289.5		—		—		289.5
Securitization recovery trust account	2.0			—		—		2.0		2.0		—		—		2.0
Financial transmission rights	—			—		10.2		10.2		—		—		10.2		10.2
		$480.1			$350.5		$10.2		$1,643.9		$480.1		$350.5		$10.2		$1,643.9

Liabilities:
Gas hedge contracts		$5.0			$—		$—		$5.0		$5.0		$—		$—		$5.0

Entergy Mississippi


2018	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
	(In Millions)								(In Millions)
Assets:
Escrow accounts		$32.2		$—		$—		$32.2	$32.3			$—		$—	$32.3
Gas hedge contracts	0.5		—		—		0.5		0.4		—		—		0.4
Financial transmission rights	—		—		4.4		4.4		—		—		3.7		3.7
		$32.7		$—		$4.4		$37.1		$32.7		$—		$3.7		$36.4

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Notes to Financial Statements



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

Entergy New Orleans


2018	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
	(In Millions)								(In Millions)
Assets:
Temporary cash investments										$32.9		$—		$—		$32.9
Securitization recovery trust account		$1.5		$—		$—		$1.5	5.6		—		—		5.6
Escrow accounts	80.1		—		—		80.1		80.4		—		—		80.4
Financial transmission rights	—		—		3.0		3.0		—		—		2.1		2.1
		$81.6		$—		$3.0		$84.6		$118.9		$—		$2.1		$121.0



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

Entergy Texas


2018	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
	(In Millions)								(In Millions)
Assets:
Temporary cash investments		$40.4		$—		$—		$40.4		$19.0		$—		$—		$19.0
Securitization recovery trust account	31.2		—		—		31.2		33.7		—		—		33.7
Financial transmission rights	—		—		4.7		4.7		—		—		0.1		0.1
		$71.6		$—		$4.7		$76.3		$52.7		$—		$0.1		$52.8

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Notes to Financial Statements



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

System Energy


2018	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
	(In Millions)								(In Millions)
Assets:
Temporary cash investments		$258.7		$—		$—		$258.7		$254.4		$—		$—		$254.4
Decommissioning trust funds (a):
Equity securities	5.0		—		—		5.0		7.4		—		—		7.4
Debt securities	178.7		145.5		—		324.2		211.1		148.1		—		359.2
Common trusts (b)							585.2								585.8
		$442.4		$145.5		$—		$1,173.1		$472.9		$148.1		$—		$1,206.8



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


(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.

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Notes to Financial Statements

Entergy
Arkansas Entergy
Louisiana Entergy
Mississippi Entergy
New
Orleans Entergy
Texas
(In Millions)
Balance as of April 1, 2018
$1.8

$3.4

$0.9

$0.7

$1.4
Issuances of financial transmission rights 11.8
20.0
4.5
3.7
6.1
Gains included as a regulatory liability/asset (1.0 ) 20.6
8.8
3.8
(4.6 )
Settlements (2.1 ) (25.8 ) (9.8 ) (5.2 ) 1.8
Balance as of June 30, 2018
$10.5

$18.2

$4.4

$3.0

$4.7



	Entergy Arkansas			Entergy Louisiana			Entergy Mississippi			Entergy New Orleans			Entergy Texas
	(In Millions)
Balance as of July 1, 2018		$10.5			$18.2			$4.4			$3.0			$4.7
Gains included as a regulatory liability/asset	10.9			7.6			4.7			1.1			(5.0		)
Settlements	(10.1		)	(13.8		)	(5.4		)	(2.0		)	0.4
Balance as of September 30, 2018		$11.3			$12.0			$3.7			$2.1			$0.1

Entergy
Arkansas Entergy
Louisiana Entergy
Mississippi Entergy
New
Orleans Entergy
Texas
(In Millions)
Balance as of April 1, 2017
$0.9

$4.1

$1.3

$0.5

$1.0
Issuances of financial transmission rights 8.9
31.0
9.6
5.0
7.1
Gains included as a regulatory liability/asset 9.0
7.5
6.7
3.1
4.3
Settlements (10.5 ) (14.3 ) (8.5 ) (3.4 ) (6.9 )
Balance as of June 30, 2017
$8.3

$28.3

$9.1

$5.2

$5.5



	Entergy Arkansas			Entergy Louisiana			Entergy Mississippi			Entergy New Orleans			Entergy Texas
	(In Millions)
Balance as of July 1, 2017		$8.3			$28.3			$9.1			$5.2			$5.5
Gains included as a regulatory liability/asset	0.3			(0.1		)	1.1			0.2			6.5
Settlements	(4.2		)	(9.4		)	(4.7		)	(1.9		)	(7.0		)
Balance as of September 30, 2017		$4.4			$18.8			$5.5			$3.5			$5.0

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the ~~six~~nine months ended ~~June~~September 30, 2018.


	Entergy Arkansas			Entergy Louisiana			Entergy Mississippi			Entergy New Orleans			Entergy Texas			Entergy Arkansas			Entergy Louisiana			Entergy Mississippi			Entergy New Orleans			Entergy Texas
	(In Millions)															(In Millions)
Balance as of January 1, 2018		$3.0			$10.2			$2.1			$2.2			$3.4			$3.0			$10.2			$2.1			$2.2			$3.4
Issuances of financial transmission rights	11.8			20.0			4.5			3.7			6.1			11.8			20.0			4.5			3.7			6.1
Gains included as a regulatory liability/asset	5.8			31.4			15.4			5.5			(10.1		)	16.6			39.0			20.1			6.7			(15.0		)
Settlements	(10.1		)	(43.4		)	(17.6		)	(8.4		)	5.3			(20.1		)	(57.2		)	(23.0		)	(10.5		)	5.6
Balance as of June 30, 2018		$10.5			$18.2			$4.4			$3.0			$4.7
Balance as of September 30, 2018																	$11.3			$12.0			$3.7			$2.1			$0.1

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Notes to Financial Statements

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the ~~six~~nine months ended ~~June~~September 30, 2017.


	Entergy Arkansas			Entergy Louisiana			Entergy Mississippi			Entergy New Orleans			Entergy Texas			Entergy Arkansas			Entergy Louisiana			Entergy Mississippi			Entergy New Orleans			Entergy Texas
	(In Millions)															(In Millions)
Balance as of January 1, 2017		$5.4			$8.5			$3.2			$1.1			$3.1			$5.4			$8.5			$3.2			$1.1			$3.1
Issuances of financial transmission rights	8.9			31.0			9.6			5.0			7.1			8.9			31.0			9.6			5.0			7.1
Gains (losses) included as a regulatory liability/asset	9.1			18.3			7.9			4.8			7.4			9.4			18.2			9.0			5.1			14.0
Settlements	(15.1		)	(29.5		)	(11.6		)	(5.7		)	(12.1		)	(19.3		)	(38.9		)	(16.3		)	(7.7		)	(19.2		)
Balance as of June 30, 2017		$8.3			$28.3			$9.1			$5.2			$5.5
Balance as of September 30, 2017																	$4.4			$18.8			$5.5			$3.5			$5.0

NOTE 9. 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 nuclear decommissioning 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~~Entergy’s nuclear decommissioning trust funds ~~are invested primarily~~invest 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 increasing 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,~~Beginning in 2018, 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~~unrealized 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. A portion of Entergy’s decommissioning trust funds are held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

held in the registered investment company are recognized 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.

~~Table of Contents~~

~~Entergy Corporation and Subsidiaries~~

~~Notes to Financial Statements~~

The unrealized gains/(losses) recognized during the three and ~~six~~nine months ended ~~June~~September 30, 2018 on equity securities still held as of ~~June~~September 30, 2018 were ~~$100~~$369 million and ~~$33~~$464 million, respectively. 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 ~~June~~September 30, 2018 and December 31, 2017 are summarized as follows:


	Fair Value		Total Unrealized Gains		Total Unrealized Losses		Fair Value		Total Unrealized Gains		Total Unrealized Losses
	(In Millions)						(In Millions)
2018
Debt Securities		$2,620		$20		$53
Debt Securities (a)								$2,448		$10		$51

2017
Equity Securities		$4,662		$2,131		$1		$4,662		$2,131		$1
Debt Securities	2,550		44		16		2,550		44		16
Total		$7,212		$2,175		$17		$7,212		$2,175		$17


(a)	Debt securities presented herein do not include the $397 million of debt securities held in the wholly-owned registered investment company, which are not accounted for as available-for-sale.

The unrealized gains/(losses) above are reported before deferred taxes of $472 million as of December 31, 2017 for equity securities, and ($5)6) million as of ~~June~~September 30, 2018 and $7 million as of December 31, 2017 for debt securities. The amortized cost of available-for-sale debt securities was ~~$2,653~~$2,489 million as of ~~June~~September 30, 2018 and $2,539 million as of December 31, 2017. As of ~~June~~September 30, 2018, ~~the~~available-for-sale debt securities have an average coupon rate of approximately ~~3.31%~~3.36%, an average duration of approximately ~~6.77~~5.98 years, and an average maturity of approximately ~~10.06~~10.4 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 ~~June~~September 30, 2018:


	Debt Securities				Debt Securities
	Fair Value		Gross Unrealized Losses		Fair Value		Gross Unrealized Losses
	(In Millions)				(In Millions)
Less than 12 months		$1,624		$40		$1,691		$33
More than 12 months	229		13		357		18
Total		$1,853		$53		$2,048		$51

Table of Contents

Entergy Corporation and Subsidiaries

Notes to Financial Statements

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

~~Table of Contents~~

~~Entergy Corporation and Subsidiaries~~

~~Notes to Financial Statements~~

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of ~~June~~September 30, 2018 and December 31, 2017 are as follows:


	2018		2017		2018		2017
	(In Millions)				(In Millions)
less than 1 year		$131		$74		$119		$74
1 year - 5 years	963		902		934		902
5 years - 10 years	693		812		628		812
10 years - 15 years	148		147		108		147
15 years - 20 years	105		100		92		100
20 years+	580		515		567		515
Total		$2,620		$2,550		$2,448		$2,550

During the three months ended ~~June~~September 30, 2018 and 2017, proceeds from the dispositions of securities amounted to ~~$710~~$2,377 million and ~~$949~~$440 million, respectively. During the three months ended ~~June~~September 30, 2018 and 2017, gross gains of $1$4 million and ~~$61~~$9 million, respectively, and gross losses of $15 million and $2 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

During the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017, proceeds from the dispositions of securities amounted to ~~$1,801~~$4,178 million and ~~$1,463~~$1,903 million, respectively. During the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017, gross gains of $2$6 million and ~~$70~~$79 million, respectively, and gross losses of ~~$22~~$37 million and $7$9 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 ~~June~~September 30, 2018 are ~~$491~~$509 million for Indian Point 1, ~~$621~~$644 million for Indian Point 2, ~~$801~~$835 million for Indian Point 3, ~~$460~~$476 million for Palisades, ~~$1,055~~$1,081 million for Pilgrim, and ~~$585~~$554 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 ~~June~~September 30, 2018 and December 31, 2017 are summarized as follows:

Fair
Value

Total
Unrealized
Gains

Total
Unrealized
Losses
(In Millions)
2018
Debt Securities
$341.7

$0.4

$9.9

2017
Equity Securities
$596.7

$354.9

$—
Debt Securities 348.2
2.1
3.0
Total
$944.9

$357.0

$3.0

8590

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Entergy Corporation and Subsidiaries

Notes to Financial Statements



	Fair Value		Total Unrealized Gains		Total Unrealized Losses
	(In Millions)
2018
Debt Securities		$378.5		$0.2		$10.9

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 available-for-sale debt securities was ~~$351.2~~$389.2 million as of ~~June~~September 30, 2018 and $349.1 million as of December 31, 2017. As of ~~June~~September 30, 2018, ~~the~~available-for-sale debt securities have an average coupon rate of approximately ~~2.64%~~2.68%, an average duration of approximately ~~4.72~~4.6 years, and an average maturity of approximately ~~6.38~~6.47 years.

The unrealized gains/(losses) recognized during the three and ~~six~~nine months ended ~~June~~September 30, 2018 on equity securities still held as of ~~June~~September 30, 2018 were ~~$16.8~~$37.8 million and ~~$8.9~~$46 million, respectively. 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.


	Debt Securities				Debt Securities
	Fair Value		Gross Unrealized Losses		Fair Value		Gross Unrealized Losses
	(In Millions)				(In Millions)
Less than 12 months		$266.6		$7.9		$259.7		$6.8
More than 12 months	34.4		2.0		78.2		4.1
Total		$301.0		$9.9		$337.9		$10.9

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 June 30, 2018 and December 31, 2017 are as follows:~~

2018 2017
(In Millions)
less than 1 year
$29.5

$13.0
1 year - 5 years 161.6
123.4
5 years - 10 years 115.4
180.6
10 years - 15 years 3.4
4.8
15 years - 20 years 5.9
3.4
20 years+ 25.9
23.0
Total
$341.7

$348.2

~~During the three months ended~~June 30, 2018 and 2017, proceeds from the dispositions of securities amounted to $86.5 million and $131.3 million, respectively. During the three months ended June 30, 2018 and 2017, gross gains of $0.01 million and $11.2 million, respectively, and gross losses of $2.3 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

8691

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows:



	2018		2017
	(In Millions)
less than 1 year		$40.8		$13.0
1 year - 5 years	174.4		123.4
5 years - 10 years	115.6		180.6
10 years - 15 years	10.6		4.8
15 years - 20 years	5.8		3.4
20 years+	31.3		23.0
Total		$378.5		$348.2

During the ~~six~~three months ended ~~June~~September 30, 2018 and 2017, proceeds from the dispositions of securities amounted to ~~$121.4~~$137.9 million and ~~$167.3~~$51.9 million, respectively. During the ~~six~~three months ended ~~June~~September 30, 2018 and 2017, gross gains of $0.01 million and $0.04 million, respectively, and gross losses of $0.6 million and $0.5 thousand, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

During the nine months endedSeptember 30, 2018 and 2017, proceeds from the dispositions of securities amounted to $259.3 million and $219.2 million, respectively. During the nine months ended September 30, 2018 and 2017, gross gains of $0.1 million and $11.7 million, respectively, and gross losses of ~~$2.4~~$3 million and $0.2 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 ~~June~~September 30, 2018 and December 31, 2017 are summarized as follows:


	Fair Value		Total Unrealized Gains		Total Unrealized Losses		Fair Value		Total Unrealized Gains		Total Unrealized Losses
	(In Millions)						(In Millions)
2018
Debt Securities		$513.8		$4.7		$10.3		$520.5		$2.0		$9.3

2017
Equity Securities		$818.3		$461.2		$—		$818.3		$461.2		$—
Debt Securities	493.8		10.9		3.6		493.8		10.9		3.6
Total		$1,312.1		$472.1		$3.6		$1,312.1		$472.1		$3.6

The amortized cost of available-for-sale debt securities was ~~$519.3~~$527.8 million as of ~~June~~September 30, 2018 and $490 million as of December 31, 2017. As of ~~June~~September 30, 2018, the available-for-sale debt securities have an average coupon rate of approximately ~~3.79%~~4.07%, an average duration of approximately ~~5.86~~6.74 years, and an average maturity of approximately ~~11.64~~13.75 years.

Table of Contents

Entergy Corporation and Subsidiaries

Notes to Financial Statements

are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2018:



	Debt Securities
	Fair Value		Gross Unrealized Losses
	(In Millions)
Less than 12 months		$355.6		$5.8
More than 12 months	74.0		3.5
Total		$429.6		$9.3



	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 available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2018 and December 31, 2017 are as follows:



	2018		2017
	(In Millions)
less than 1 year		$22.4		$23.2
1 year - 5 years	122.0		122.8
5 years - 10 years	117.9		109.3
10 years - 15 years	37.7		52.7
15 years - 20 years	41.3		50.7
20 years+	179.2		135.1
Total		$520.5		$493.8

During the three months ended September 30, 2018 and 2017, proceeds from the dispositions of securities amounted to $773.9 million and $50.5 million, respectively. During the three months ended September 30, 2018 and 2017, gross gains of $1.9 million and $2.9 million, respectively, and gross losses of $3.6 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

During the nine months ended September 30, 2018 and 2017, proceeds from the dispositions of securities amounted to $943.3 million and $176.1 million, respectively. During the nine months ended September 30, 2018 and 2017, gross gains of $2.5 million and $7.9 million, respectively, and gross losses of $4.8 million and $0.4 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Table of Contents

Entergy Corporation and Subsidiaries

Notes to Financial Statements

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 September 30, 2018 and December 31, 2017 are summarized as follows:



	Fair Value		Total Unrealized Gains		Total Unrealized Losses
	(In Millions)
2018
Debt Securities		$359.2		$0.9		$7.1

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 available-for-sale debt securities was $365.5 million as of September 30, 2018 and $327.5 million as of December 31, 2017. As of September 30, 2018, available-for-sale debt securities have an average coupon rate of approximately 2.95%, an average duration of approximately 6.2 years, and an average maturity of approximately 9.08 years.

The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2018 on equity securities still held as of September 30, 2018 were $35.9 million and $43.8 million, respectively. 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.


	Debt Securities					Debt Securities
	Fair Value		Gross Unrealized Losses			Fair Value		Gross Unrealized Losses
	(In Millions)				(In Millions)
Less than 12 months		$287.6		$6.3			$267.6		$5.2
More than 12 months	75.5		4.0			34.3		1.9
Total		$363.1		$10.3			$301.9		$7.1

8794

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Entergy Corporation and Subsidiaries

Notes to Financial Statements


	Equity Securities				Debt Securities				Equity Securities				Debt Securities
	Fair Value		Gross Unrealized Losses		Fair Value		Gross Unrealized Losses		Fair Value		Gross Unrealized Losses		Fair Value		Gross Unrealized Losses
	(In Millions)								(In Millions)
Less than 12 months		$—		$—		$135.3		$1.1		$—		$—		$196.9		$1.0
More than 12 months	—		—		84.4		2.5		—		—		10.4		0.2
Total		$—		$—		$219.7		$3.6		$—		$—		$207.3		$1.2

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of ~~June~~September 30, 2018 and December 31, 2017 are as follows:


	2018		2017		2018		2017
	(In Millions)				(In Millions)
less than 1 year		$29.5		$23.2		$2.2		$4.1
1 year - 5 years	140.5		122.8		195.4		173.0
5 years - 10 years	101.7		109.3		78.2		78.5
10 years - 15 years	53.7		52.7		5.6		1.0
15 years - 20 years	45.0		50.7		11.0		6.9
20 years+	143.4		135.1		66.8		67.0
Total		$513.8		$493.8		$359.2		$330.5

During the three months ended ~~June~~September 30, 2018 and 2017, proceeds from the dispositions of securities amounted to ~~$43.9~~$157.8 million and ~~$85~~$54.6 million, respectively. During the three months ended ~~June~~September 30, 2018 and 2017, gross gains of ~~$0.01 million~~$6.5 thousand and $5$0.2 million, respectively, and gross losses of ~~$0.4~~$0.3 million and ~~0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.~~

During the six months ended June 30, 2018 and 2017, proceeds from the dispositions of securities amounted to $169.4 million and $125.6 million, respectively. During the six months ended June 30, 2018 and 2017, gross gains of $0.5 million and $5 million, respectively, and gross losses of $1.2 million and $0.3 million~~, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.~~

~~Table of Contents~~

~~Entergy Corporation and Subsidiaries~~

~~Notes to Financial Statements~~

~~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 June 30, 2018 and December 31, 2017 are summarized as follows:

Fair
Value

Total
Unrealized
Gains

Total
Unrealized
Losses
(In Millions)
2018
Debt Securities
$324.2

$1.6

$5.7

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 $328.3 million as of June 30, 2018 and $327.5 million as of December 31, 2017. As of June 30, 2018, the debt securities have an average coupon rate of approximately 2.93%, an average duration of approximately 6.22 years, and an average maturity of approximately 9.12 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2018 on equity securities still held as of June 30, 2018 were $16.3 million and $8.5 million, respectively. 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 June 30, 2018:

Debt Securities

Fair
Value

Gross
Unrealized
Losses
(In Millions)
Less than 12 months
$187.0

$5.1
More than 12 months 9.2
0.6
Total
$196.2

$5.7

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

~~Table of Contents~~

~~Entergy Corporation and Subsidiaries~~

~~Notes to Financial Statements~~

~~The fair value of debt securities, summarized by contractual maturities, as of June 30, 2018 and December 31, 2017 are as follows:~~

2018 2017
(In Millions)
less than 1 year
$9.7

$4.1
1 year - 5 years 169.2
173.0
5 years - 10 years 71.6
78.5
10 years - 15 years 2.7
1.0
15 years - 20 years 11.3
6.9
20 years+ 59.7
67.0
Total
$324.2

$330.5

During the three months ended June 30, 2018 and 2017, proceeds from the dispositions of securities amounted to $145.2 million and $177.7 million, respectively. During the three months ended June 30, 2018 and 2017, gross gains of $0.2 ~~million and $0.4 million, respectively, and gross losses of $3.9 million and $0.6~~ million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

During the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017, proceeds from the dispositions of securities amounted to ~~$199.4~~$357.2 million and ~~$253.5~~$308.1 million, respectively. During the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017, gross gains of $0.3 million and ~~$0.5~~$0.7 million, respectively, and gross losses of ~~$4.5~~$4.8 million and ~~$1.3~~$1.5 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 and ~~six~~nine months ended ~~June~~September 30, 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.

Table of Contents

Entergy Corporation and Subsidiaries

Notes to Financial Statements

NOTE 10. 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.

2012-2013 IRS Audit

The IRS ~~has~~ completed its examination of the 2012 and 2013 tax years and issued its 2012-2013 Revenue Agent Report (RAR) in June 2018. Entergy ~~has~~ agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of these adjustments in June 2018.

~~Table of Contents~~

~~Entergy Corporation and Subsidiaries~~

~~Notes to Financial Statements~~

As a result of the issuance of the RAR, Entergy Louisiana was able to recognize previously unrecognized tax benefits of $52 million related to the Hurricane Katrina and Hurricane Rita contingent sharing obligation associated with the Louisiana Act 55 financing.

The conclusion and settlement of the ~~above-described item, along with other minor recorded adjustments, decreased~~IRS audit described above caused a decrease in Entergy Louisiana’s balance of unrecognized tax benefits, which changed from $926 million as of December 31, 2017 to ~~$856~~$855 million as of ~~June~~September 30, 2018, net of carryovers for losses and credits. The reduction of unrecognized tax benefits was primarily recorded in the second quarter 2018 with no significant additional changes to Entergy Louisiana’s unrecognized tax benefit balance recognized during the third quarter 2018.

Tax Cuts and Jobs Act

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 limitations in 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.

During the second ~~quarter~~and third quarters of 2018, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans and System Energy began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by each ~~operating company’s~~Registrant Subsidiary’s respective regulatory commission. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. In the ~~second~~third quarter 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy Arkansas, ~~$108~~$153 million; Entergy Louisiana, ~~$31~~$55 million; Entergy Mississippi, ~~$129~~$32 million; Entergy New Orleans, $9 million; and System Energy, $34 million. In the nine months ended September 30, 2018 the return of unprotected excess accumulated deferred income taxes reduced the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Entergy ~~$11~~Arkansas, $260 million; Entergy Louisiana, $86 million; Entergy Mississippi, $161 million; Entergy New Orleans, $9 million; and System Energy, $46 million.

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Notes to Financial Statements

As discussed in Note 2 to the financial statements herein, the unopposed settlement of Entergy Texas’s 2018 rate case, if approved by the PUCT, establishes the amounts of protected and unprotected excess accumulated deferred income taxes that Entergy Texas will return to customers. As of September 30, 2018, Entergy Texas’s regulatory liability for protected excess accumulated deferred income taxes was $269 million and its regulatory liability for unprotected excess accumulated deferred income taxes was $201 million.

Other Tax Matters

In the third quarter 2018, Entergy completed a restructuring of the investment holdings in one of the Entergy Wholesale Commodities nuclear plant decommissioning trusts that resulted in an adjustment to tax basis for the trust. The accounting standards provide that a taxable temporary difference does not exist if the tax law provides a means by which an amount can be recovered without incurrence of tax. The restructuring allows Entergy to recover assets from the trust without incurring tax. As such, the tax basis recognized resulted in the reversal of a deferred tax liability and reduction of income tax expense of approximately $107 million.

A state income tax audit involving Entergy Wholesale Commodities was concluded during the third quarter 2018. Upon conclusion of the audit, subsidiaries within Entergy Wholesale Commodities reversed a portion of the provision for uncertain tax positions totaling approximately $23 million, net of tax and interest paid.

NOTE 11. PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Construction Expenditures in Accounts Payable

Construction expenditures included in accounts payable at ~~June~~September 30, 2018 are ~~$280~~$255 million for Entergy, ~~$30.3~~$27.8 million for Entergy Arkansas, ~~$113.5~~$80.1 million for Entergy Louisiana, ~~$15.2~~$8.9 million for Entergy Mississippi, ~~$4.8~~$18.7 million for Entergy New Orleans, ~~$7.1~~$13.9 million for Entergy Texas, and ~~$53~~$38.1 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.

NOTE 12. 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.

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~~Notes to Financial Statements~~

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments on its lease, including interest, of $8.6 million in the ~~six~~three months ended ~~June~~September 30, 2018 and ~~$8.6~~in the three months ended September 30, 2017. System Energy made payments on its lease, including interest, of $17.2 million in the ~~six~~nine months ended ~~June~~September 30, 2018 and in the nine months ended September 30, 2017.

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Notes to Financial Statements

NOTE 13. 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 or ~~six~~nine months ended ~~June~~September 30, 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.

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~~Notes to Financial Statements~~

Entergy’s total revenues for the three and ~~six~~nine months ended ~~June~~September 30, 2018 were as follows:


	2018						2018
	Three Months Ended			Six Months Ended			Three Months Ended			Nine Months Ended
	(In Thousands)						(In Thousands)
Utility:
Residential		$768,710			$1,660,795			$1,138,744			$2,799,539
Commercial	581,899			1,177,620			693,760			1,871,380
Industrial	624,818			1,222,004			682,823			1,904,828
Governmental	56,823			113,301			60,647			173,949
Total billed retail	2,032,250			4,173,720			2,575,974			6,749,696

Sales for resale (a)	69,212			138,738			76,247			214,984
Other electric revenues (b)	219,391			246,822			42,847			289,668
Non-customer revenues (c)	9,372			19,206			2,819			22,026
Total electric revenues	2,330,225			4,578,486			2,697,887			7,276,374

Natural gas	29,943			86,638			26,352			112,990

Entergy Wholesale Commodities:
Competitive businesses sales (a)	331,562			740,697			407,763			1,148,460
Non-customer revenues (c)	(22,960		)	(13,171		)	(27,683		)	(40,854		)
Total competitive businesses	308,602			727,526			380,080			1,107,606

Total operating revenues		$2,668,770			$5,392,650			$3,104,319			$8,496,970

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The Registrant Subsidiaries’ total revenues for the three months ended ~~June~~September 30, 2018 were as follows:


2018	Entergy Arkansas		Entergy Louisiana		Entergy Mississippi		Entergy New Orleans		Entergy Texas		Entergy Arkansas		Entergy Louisiana			Entergy Mississippi		Entergy New Orleans			Entergy Texas
	(In Thousands)										(In Thousands)

Residential		$159,130		$267,915		$132,730		$58,232		$150,703		$250,081		$408,680			$170,258		$86,014			$223,711
Commercial	93,741		221,740		117,351		54,524		94,544		119,950		272,985			126,987		62,428			111,409
Industrial	97,973		368,678		46,129		9,267		102,771		126,079		393,884			44,383		9,655			108,823
Governmental	3,766		16,705		11,452		18,448		6,452		4,445		17,566			11,488		20,364			6,785
Total billed retail	354,610		875,038		307,662		140,471		354,470		500,555		1,093,115			353,116		178,461			450,728

Sales for resale (a)	53,195		111,801		11,776		6,190		25,177		60,338		71,634			7,876		4,863			23,290
Other electric revenues (b)	84,102		70,027		31,696		11,623		23,468		4,446		34,220			4,079		(1,107		)	2,735
Non-customer revenues (c)	2,698		4,823		2,555		1,318		371		3,060		(2,691		)	2,663		1,947			478
Total electric revenues	494,605		1,061,689		353,689		159,602		403,486		568,399		1,196,278			367,734		184,164			477,231

Natural gas	—		11,099		—		18,844		—		—		10,334			—		16,018			—

Total operating revenues		$494,605		$1,072,788		$353,689		$178,446		$403,486		$568,399		$1,206,612			$367,734		$200,182			$477,231

The Registrant Subsidiaries’ total revenues for the ~~six~~nine months ended ~~June~~September 30, 2018 were as follows:


2018	Entergy Arkansas		Entergy Louisiana		Entergy Mississippi		Entergy New Orleans		Entergy Texas		Entergy Arkansas		Entergy Louisiana		Entergy Mississippi		Entergy New Orleans		Entergy Texas
	(In Thousands)										(In Thousands)

Residential		$394,654		$563,433		$281,073		$122,807		$298,828		$644,735		$972,113		$451,331		$208,821		$522,539
Commercial	214,375		446,667		227,811		108,796		179,971		334,325		719,652		354,799		171,224		291,380
Industrial	209,450		721,014		88,629		16,838		186,073		335,529		1,114,898		133,012		26,493		294,896
Governmental	8,414		34,015		22,300		36,139		12,433		12,859		51,581		33,788		56,503		19,218
Total billed retail	826,893		1,765,129		619,813		284,580		677,305		1,327,448		2,858,244		972,930		463,041		1,128,033

Sales for resale (a)	119,299		201,056		13,769		19,527		48,538		179,637		272,690		21,645		24,390		71,828
Other electric revenues (b)	94,125		90,529		30,977		8,511		25,733		98,571		124,749		35,055		7,404		28,468
Non-customer revenues (c)	5,312		10,081		4,873		2,802		850		8,372		7,390		7,536		4,749		1,328
Total electric revenues	1,045,629		2,066,795		669,432		315,420		752,426		1,614,028		3,263,073		1,037,166		499,584		1,229,657

Natural gas	—		35,337		—		51,301		—		—		45,671		—		67,319		—

Total operating revenues		$1,045,629		$2,102,132		$669,432		$366,721		$752,426		$1,614,028		$3,308,744		$1,037,166		$566,903		$1,229,657


(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

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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.

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Notes to Financial Statements

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.

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Notes to Financial Statements

NOTE 14. 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. The following ~~is an update~~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.

As discussed in the Form 10-K, Entergy Wholesale Commodities plant owners will submit filings with the NRC for planned shutdown activities as the nuclear plants individually approach and begin decommissioning. Entergy Nuclear Generation Company expects to file its Post-Shutdown Decommissioning Activities Report (PSDAR) with the NRC in the fourth quarter 2018 for the Pilgrim plant. As part of the development of the PSDAR, Entergy obtained a revised decommissioning cost study in the third quarter 2018. The revised estimate resulted in a $117.5 million increase in the decommissioning cost liability and a corresponding impairment charge. See Note 14 to the financial statements in the Form 10-K for a discussion of impairment of the Pilgrim plant.

________________

In the opinion of the management of Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy, the accompanying unaudited financial statements contain all adjustments (consisting primarily of normal recurring accruals and reclassification of previously reported amounts to conform to current classifications) necessary for a fair statement of the results for the interim periods presented. Entergy’s business is subject to seasonal fluctuations, however, with peak periods occurring typically during the first and third quarters. The results for the interim periods presented should not be used as a basis for estimating results of operations for a full year.

Part I, Item 3. Quantitative and Qualitative Disclosures About Market Risk

See “Market and Credit Risk Sensitive Instruments” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis.

Part I, Item 4. Controls and Procedures

Disclosure Controls and Procedures

As of ~~June~~September 30, 2018, evaluations were performed under the supervision and with the participation of Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy (individually “Registrant” and collectively the “Registrants”) management, including their respective Principal Executive Officers (PEO) and Principal Financial Officers (PFO). The evaluations assessed the effectiveness of the Registrants’ disclosure controls and procedures. Based on the evaluations, each PEO and PFO has concluded that, as to the Registrant or Registrants for which they serve as PEO or PFO, the Registrant’s or Registrants’ disclosure controls and procedures are effective to ensure that information required to be disclosed by each Registrant in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in Securities and Exchange Commission rules and forms; and that the Registrant’s or Registrants’ disclosure controls and procedures are also effective in reasonably assuring that such information is accumulated and communicated to the Registrant’s or Registrants’ management, including their respective PEOs and PFOs, as appropriate to allow timely decisions regarding required disclosure.

Changes in Internal Controls over Financial Reporting

Under the supervision and with the participation of each Registrants’ management, including its respective PEO and PFO, each Registrant evaluated changes in internal control over financial reporting that occurred during the quarter ended ~~June~~September 30, 2018 and found no change that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

ENTERGY ARKANSAS, INC. AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter 2017

Net income increased ~~$44~~$36.3 million primarily due to a lower effective income tax rate and higher net revenue, after excluding the effect of the return of unprotected excess accumulated deferred income taxes to customers which is offset in income taxes, ~~and a lower effective income tax rate,~~ partially offset by ~~lower other income and~~ higher other operation and maintenance expenses.

~~Six~~Nine Months Ended ~~June~~September 30, 2018 Compared to ~~Six~~Nine Months Ended ~~June~~September 30, 2017

Net income increased ~~$66~~$102.2 million primarily due to ~~higher net revenue and~~ a lower effective income tax rate and higher net revenue, after excluding the effect of the return of unprotected excess accumulated deferred income taxes to customers which is offset in income taxes, partially offset by higher other operation and maintenance expenses, ~~lower other income, and~~ higher depreciation and amortization ~~expenses.~~expenses, and lower other income.

Net Revenue

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter 2017

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory ~~charges (credits).~~credits. Following is an analysis of the change in net revenue comparing the ~~second~~third quarter 2018 to the ~~second~~third quarter 2017:



	Amount
	(In Millions)
2017 net revenue		$~~366.5~~481.8
Return of unprotected excess accumulated deferred income taxes to customers	(~~107.6~~152.8		)
Volume/weather	10.9
Retail electric price	25.6
Other	(6.0		)
2018 net revenue		$359.5

The return of unprotected excess accumulated deferred income taxes to customers resulted from the return of unprotected excess accumulated deferred income taxes through a tax adjustment rider beginning in April 2018. There is no effect on net income as the reduction in net revenue was offset by a reduction in income tax expense. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

The volume/weather variance is primarily due to an increase of 548 GWh, or 9%, in billed electricity usage, including the effect of more favorable weather on residential and commercial sales and an increase in industrial usage. The increase in industrial usage is primarily due to an increase in demand from mid-size to small customers and a new customer in the primary metals industry.

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The retail electric price variance is primarily due to an increase in formula rate plan rates effective with the first billing cycle of January 2018 and an increase in the energy efficiency rider effective January 2018, each as approved by the APSC. See Note 2 to the financial statements in the Form 10-K for further discussion of the formula rate plan filing.

Nine Months Ended September 30, 2018 Compared to Nine Months Ended September 30, 2017

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory credits. Following is an analysis of the change in net revenue comparing the nine months ended September 30, 2018 to the nine months ended September 30, 2017:



	Amount
	(In Millions)
2017 net revenue		$1,178.6
Return of unprotected excess accumulated deferred income taxes to customers	(260.4		)
Retail electric price	~~20.1~~68.2
Volume/weather	~~46.7~~78.0
Other	~~9.9~~4.7
2018 net revenue		$~~335.6~~1,069.1

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~~Entergy Arkansas, Inc. and Subsidiaries~~

~~Management's Financial Discussion and Analysis~~

The volume/weather variance is primarily due to an increase of ~~331~~1,478 GWh, or 7%9%, in billed electricity usage, including the effect of more favorable weather on residential and commercial sales and an increase in industrial usage. The increase in industrial usage is primarily due to a new customer in the primary metals ~~industry.~~

~~Six Months Ended June 30, 2018 Compared to Six Months Ended June 30, 2017~~

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory credits. Following is an analysis of the change in net revenue comparing the six months ended June 30, 2018 to the six months ended June 30, 2017:



	~~Amount~~
	~~(In Millions)~~
~~2017 net revenue~~		~~$696.8~~
~~Volume/weather~~	~~67.1~~
~~Retail electric price~~	~~42.5~~
~~Return of unprotected excess accumulated deferred income taxes to customers~~	~~(107.6~~		)
~~Other~~	~~10.8~~
~~2018 net revenue~~		~~$709.6~~

~~The volume/weather variance is primarily due to an increase of 930 GWh, or 10%, in billed electricity usage, including the effect of more favorable weather on residential and commercial sales~~industry and an increase in ~~industrial usage. The increase in industrial usage is primarily due~~demand from mid-size to ~~a new customer in the primary metals industry.~~

Other Income Statement Variances

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter 2017

Other operation and maintenance expenses increased primarily due to an increase of $8.5 million in energy efficiency costs and an increase of $6.8 million in fossil-fueled generation expenses primarily due to higher long-term service agreement costs and higher labor costs in the third quarter 2018 as compared to the same period in 2017.

Depreciation and amortization expenses increased primarily due to additions to plant in service.

Other income increased primarily due to changes in decommissioning trust fund investment activity, including portfolio rebalancing for the ANO 1 decommissioning trust fund in third quarter 2018.

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Nine Months Ended September 30, 2018 Compared to Nine Months Ended September 30, 2017

Other operation and maintenance expenses increased primarily due to:

an increase of ~~$5.7~~$14.2 million in energy efficiency costs;

an increase of $11 million in fossil-fueled generation expenses primarily due to a higher ~~scope of work performed during plant outages~~long-term service agreement costs and higher labor costs in 2018 as compared to the same period in 2017;

~~higher energy efficiency expenses of $3.8 million due to the timing of recovery from customers in 2017;~~ and

an increase of ~~$1.4~~$9.3 million in nuclear generation expenses primarily due to higher labor costs, including contract labor, to position the nuclear fleet to meet its operational goals. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of the increased operating costs to position the nuclear fleet to meet its operational goals.

The increase was partially offset by higher nuclear insurance refunds of ~~$2.9~~$6.5 million.

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Depreciation and amortization expenses increased primarily due to additions to plant in service.

Other income decreased primarily due to changes in decommissioning trust fund investment activity, including portfolio rebalancing for the ANO 1 decommissioning trust fund in ~~second quarter 2017.~~

~~Six Months Ended June 30,~~ 2018 ~~Compared to Six Months Ended June 30, 2017~~

~~Nuclear refueling outage expenses increased primarily due to the amortization of higher costs associated with the most recent outages as compared to previous outages.~~

~~Other operation~~ and ~~maintenance expenses increased primarily due to:~~

~~an increase of $8 million in nuclear generation expenses primarily due to higher labor costs, including contract labor, to position the nuclear fleet to meet its operational goals. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS –Nuclear Matters” in the Form 10-K for a discussion of the increased operating costs to position the nuclear fleet to meet its operational goals;~~

~~higher energy efficiency expenses of $7.9 million due to the timing of recovery from customers; and~~

~~an increase of $4.2 million in fossil-fueled generation expenses primarily due to a higher scope of work performed during plant outages in 2018 as compared to the same period in 2017.~~

~~The increase was partially offset by higher nuclear insurance refunds of $6.5 million.~~

Taxes other than income taxes increased primarily due to an increase in payroll taxes and an increase in ad valorem taxes. Ad valorem taxes increased primarily due to higher assessments and higher millage rates.

~~Depreciation and amortization expenses increased primarily due to additions to plant in service.~~

~~Other income decreased primarily due to changes in decommissioning trust fund investment activity, including portfolio rebalancing for the ANO 1 decommissioning trust fund in~~ 2017.

Interest expense increased primarily due to the issuance of $250 million of 4.0% Series first mortgage bonds in May 2018 and the issuance of $220 million of 3.5% Series first mortgage bonds in May ~~2017 and the issuance of $250 million of 4.0% Series first mortgage bonds in May 2018.~~2017.

Income Taxes

The effective income tax rate was ~~(10,762.6%~~(631.3%) for the ~~second~~third quarter 2018. The difference in the effective income tax rate for the ~~second~~third quarter 2018 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, certain book and tax differences related to utility plant items, and book and tax differences related to the allowance for equity funds used during construction, partially offset by an IRS audit settlement for the 2012-2013 tax returns. See Notes 2 and 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 10 to the financial statements herein for a discussion of the IRS audit settlement.

~~The effective income tax rate was (155.6%) for the six months ended June 30, 2018. The difference in the effective income tax rate for the six months ended June 30,~~ 2018 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant ~~items.~~items, partially offset by state income taxes and the provision for uncertain tax positions. See Notes 2 and 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was ~~38.4%~~(286.4%) for the ~~second~~nine months ended September 30, 2018. The difference in the effective income tax rate for the nine months ended September 30, 2018 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Notes 2 and 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was 39% for the third quarter 2017. The difference in the effective income tax rate for the ~~second~~third quarter 2017 versus the federal statutory rate of 35% was primarily due to state income ~~taxes~~

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~~and certain book and tax differences related to utility plant items, partially offset by book and tax differences related to the allowance for equity funds used during construction.~~taxes.

The effective income tax rate was ~~40.2%~~39.4% for the ~~six~~nine months ended ~~June~~September 30, 2017. The difference in the effective income tax rate for the ~~six~~nine months ended ~~June~~September 30, 2017 versus the federal statutory rate of 35% was primarily due to state income taxes ~~a write-off of a stock-based compensation deferred tax asset,~~ and certain book and tax differences related to utility plant items, partially offset by book and tax differences related to the allowance for equity funds used during construction.

Income Tax Legislation

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uncertainties associated with accounting for the Tax Act. Note 10 to the financial statements herein contains updates to that discussion. Note 2 to the financial statements herein and in the Form 10-K contains a discussion of proceedings commenced or other responses by Entergy and Entergy’s regulators to the Tax Act.

Liquidity and Capital Resources

Cash Flow

Cash flows for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017 were as follows:


	2018			2017			2018			2017
	(In Thousands)						(In Thousands)
Cash and cash equivalents at beginning of period		$6,216			$20,509			$6,216			$20,509

Cash flow provided by (used in):
Operating activities	226,595			191,161			362,585			367,551
Investing activities	(392,234		)	(418,321		)	(574,337		)	(667,841		)
Financing activities	392,491			209,728			427,318			280,245
Net increase (decrease) in cash and cash equivalents	226,852			(17,432		)	215,566			(20,045		)

Cash and cash equivalents at end of period		$233,068			$3,077			$221,782			$464

Operating Activities

Net cash flow provided by operating activities ~~increased $35.4~~decreased $5 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to ~~the timing of recovery of fuel and purchased power costs and a decrease of $20.5 million in spending on nuclear refueling outages in 2018. The increase was partially offset by~~ the return of unprotected excess accumulated deferred income taxes to ~~customers and the timing of collection of receivables from~~ customers. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act. The decrease was partially offset by:

the timing of recovery of fuel and purchased power costs;

the effect of favorable weather on billed sales;

the timing of payments to vendors;

a decrease of $18.1 million in spending on nuclear refueling outages in 2018; and

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~~Entergy Arkansas, Inc.~~$10.3 million in pension contributions in 2018. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and ~~Subsidiaries~~

~~Management's Financial Discussion~~Note 6 to the financial statements herein for a discussion of qualified pension and ~~Analysis~~other postretirement benefits funding.

Investing Activities

Net cash flow used in investing activities decreased ~~$26.1~~$93.5 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to:

~~a decrease of $49.5~~$66 million ~~as a result of the fluctuations~~ in ~~nuclear fuel activity because of variations from year to year~~funds held on deposit in ~~the timing~~2017 for principal and ~~pricing of fuel reload requirements in the Utility business, material and service deliveries, and the timing of cash~~interest payments ~~during the nuclear fuel cycle;~~due October 1, 2017;

a decrease of ~~$16.3 million in storm spending;~~

~~a decrease of $11.7~~$32.5 million in nuclear construction expenditures primarily due to a lower scope of work performed on various nuclear projects in 2018 as compared to the same period in 2017;

~~a decrease of $9.4 million in transmission construction expenditures due to a decrease in spending on various transmission projects in 2018 as compared to the same period in 2017;~~ and

a decrease of ~~$9.1~~$18.9 million in ~~fossil-fueled generation construction expenditures due to a decrease in spending on various fossil-fueled generation projects in 2018 as compared to the same period in 2017.~~storm spending.

The decrease was partially offset by money pool ~~activity and an increase of $10.5 million in information technology construction expenditures primarily due to increased spending on various technology projects.~~activity.

Increases in Entergy Arkansas’s receivable from the money pool are a use of cash flow, and Entergy Arkansas’s receivable from the money pool increased by ~~$57.7~~$13.4 million for the ~~six~~nine months ended ~~June~~September 30, 2018. The money

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pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Entergy Arkansas’s cash provided by financing activities increased ~~$182.8~~$147.1 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to:

a $350 million capital contribution from Entergy Corporation in 2018 in anticipation of the return of unprotected excess accumulated deferred income taxes to customers and upcoming planned capital investments; ~~and~~

net long-term borrowings of ~~$16.8~~$45.5 million in 2018 on the Entergy Arkansas nuclear fuel company variable interest ~~entity.~~entity credit facility; and

the issuance of $250 million of 4.0% Series first mortgage bonds in May 2018 as compared to the issuance of $220 million of 3.5% Series first mortgage bonds in May 2017.

The increase was partially offset by:

money pool activity; and

net repayments of short-term borrowings of $50 million on the Entergy Arkansas nuclear fuel company variable interest entity credit facility in 2018 as compared to net short-term borrowings of ~~$31.4~~$23.3 million on the Entergy Arkansas nuclear fuel company variable interest entity credit facility in 2017.

Decreases in Entergy Arkansas’s payable to the money pool are a use of cash flow, and Entergy Arkansas’s payable to the money pool decreased by $166.1 million in 2018 compared to ~~decreasing~~increasing by ~~$37.6~~$43.9 million in 2017.

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

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Capital Structure

Entergy Arkansas’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio for Entergy Arkansas is primarily due to the $350 million capital contribution from Entergy Corporation in 2018.


	June 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Debt to capital	52.8	%	55.5	%	51.9	%	55.5	%
Effect of excluding the securitization bonds	(0.3	%)	(0.3	%)	(0.2	%)	(0.3	%)
Debt to capital, excluding securitization bonds (a)	52.5	%	55.2	%	51.7	%	55.2	%
Effect of subtracting cash	(1.9	%)	—	%	(1.8	%)	—	%
Net debt to net capital, excluding securitization bonds (a)	50.6	%	55.2	%	49.9	%	55.2	%


(a)	Calculation excludes the securitization bonds, which are non-recourse to Entergy Arkansas.

Net debt consists of debt less cash and cash equivalents. Debt consists of short-term borrowings and long-term debt, including the currently maturing portion. Capital consists of debt, preferred stock without sinking fund, and common equity. Net capital consists of capital less cash and cash equivalents. Entergy Arkansas uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy Arkansas’s financial condition because the securitization bonds are non-recourse to Entergy Arkansas, as more fully described in Note 5 to the financial statements in the Form 10-K. Entergy Arkansas also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Arkansas’s financial

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condition because net debt indicates Entergy Arkansas’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Arkansas’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

Entergy Arkansas is developing its capital investment plan for 2019 through 2021 and currently anticipates making $2.3 billion in capital investments during that period. The preliminary estimate includes amounts associated with specific investments such as transmission projects to enhance reliability, reduce congestion, and enable economic growth; distribution spending to enhance reliability and improve service to customers, including advanced meters and related investments; resource planning, including potential generation projects; system improvements; investments in ANO 1 and 2; software and security; and other investments. Estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints and requirements, environmental compliance, business opportunities, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital.

Entergy Arkansas’s receivables from or (payables to) the money pool were as follows:

June 30,
2018

December 31,
2017

June 30,
2017

December 31,
2016
(In Thousands)
$57,708 ($166,137) ($13,669) ($51,232)

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy Arkansas has a credit facility in the amount of $150 million scheduled to expire in ~~August 2022.~~September 2023. Entergy Arkansas also has a $20 million credit facility scheduled to expire in April 2019. The $150 million credit facility includes fronting commitments for the issuance of letters of credit against $5 million of the borrowing capacity of the facility. As of ~~June~~September 30, 2018, no cash borrowings and no letters of credit were outstanding under the credit facilities. In addition, Entergy Arkansas is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of ~~June~~September 30, 2018, a $1 million letter of credit was outstanding under Entergy Arkansas’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

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The Entergy Arkansas nuclear fuel company variable interest entity has a credit facility in the amount of $80 million scheduled to expire in ~~May 2019.~~September 2021. As of ~~June~~September 30, 2018, ~~$41.7~~$70.4 million in loans were outstanding under the credit facility for the Entergy Arkansas nuclear fuel company variable interest entity. See Note 4 to the financial statements herein for additional discussion of the nuclear fuel company variable interest entity credit facility.

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – State and Local Rate Regulation and Fuel-Cost Recovery” in the Form 10-K for a discussion of state and local rate regulation and fuel-cost recovery. The following are updates to that discussion.

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Retail Rates

2018 Formula Rate Plan Filing

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. In July 2018, Entergy Arkansas filed a settlement, reached by all parties in the APSC proceeding, resolving all ~~issues~~issues. The APSC approved the settlement agreement and ~~seeking an APSC decision no later than September 1,~~restructuring in August 2018. IfPursuant to the ~~appropriate approvals are obtained,~~settlement agreement, Entergy Arkansas ~~expects~~will credit retail customers $39.6 million over six years, beginning in 2019. Entergy Arkansas has also received the required FERC and NRC approvals. The restructuring ~~will be consummated~~is anticipated to close on or before December 1, 2018.

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 ~~Cuts and Jobs~~ 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

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~~Entergy Arkansas also stated that potential effects of the Tax Cuts and Job 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. InThe redetermined rate became effective with the first billing cycle of April 2018. Subsequently 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 at that time of the issues suggested by the Attorney General in the proceeding. Following a period of discovery, the Attorney General filed a supplemental response in October 2018 raising new issues with Entergy Arkansas’s March 2018 rate redetermination and asserting that $45.7 million of the increase should be collected subject to refund pending further investigation. Also in October 2018, Entergy Arkansas filed to dismiss the Attorney General’s supplemental response, the APSC general staff filed a motion to strike the Attorney General’s filing, and the Attorney General filed its supplemental response disputing Entergy Arkansas and the APSC staff’s filing.

Opportunity Sales Proceeding

See the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding ~~at this time. The redetermined rate became effective~~filed with the ~~first billing cycle~~FERC. In October 2018 the FERC issued an order addressing the ALJ’s July 2017 initial decision. The FERC reversed the ALJ’s decision to cap the reduction in Entergy Arkansas’s payment to account for the increased bandwidth payments that Entergy Arkansas made to the other operating companies. The FERC also reversed the ALJ’s decision that Grand Gulf sales from January through September 2000 should be included in the calculation of ~~April 2018. Discovery continues~~Entergy Arkansas’s payment. The FERC affirmed on other grounds the ALJ’s rejection of the LPSC’s claim that certain joint account sales should be accounted for as part of the calculation of Entergy Arkansas’s payment. The FERC directed Entergy to make a compliance filing by December 17, 2018 providing a final calculation of Entergy Arkansas’s payments to the other Utility operating companies pursuant to the findings in the order and explaining how Entergy Arkansas will pay refunds, including the timeline for making those refunds. The FERC’s decision effectively establishes the base amount Entergy Arkansas must pay to the other Utility operating companies for the period of 2000-2009 to be ~~conducted~~approximately $68 million. Entergy Arkansas will also pay interest on the base amount to the other Utility operating companies, currently estimated to be approximately $64 million as of September 30, 2018 for an estimated total of $132 million. This amount is consistent with the liability previously recognized by Entergy Arkansas. The December 2018 compliance filing will include the ~~parties~~recipients and final amount of payments owed by Entergy Arkansas, as well as the timing of the payments. Because management currently expects to recover the retail portion of the payments due as a result of this proceeding, Entergy Arkansas previously recognized a regulatory asset with ~~respect to that redetermined rate.~~a balance of $114 million as of September 30, 2018.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation.

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of nuclear matters. The following is an update to that discussion.

ANO

See Note 8 to the financial statements in the Form 10-K for discussion of the NRC’s decision in March 2015 to move ANO into the “multiple/repetitive degraded cornerstone column,” or Column 4, of the NRC’s Reactor Oversight Process Action Matrix, and the resulting significant additional NRC inspection activities at the ANO site. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. This action followed NRC inspections to review ANO 1’s and ANO 2’s performance in addressing issues that had previously resulted in classification in the “multiple/repetitive degraded cornerstone column,” or Column 4.

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Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Arkansas’s accounting for nuclear decommissioning costs, utility regulatory accounting, unbilled revenue, impairment of long-lived assets and trust fund investments, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of new accounting pronouncements.

																										ENTERGY ARKANSAS, INC. AND SUBSIDIARIES	CONSOLIDATED INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2018 and 2017
For the Three and Nine Months Ended September 30, 2018 and 2017													For the Three and Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Three Months Ended						Six Months Ended							Three Months Ended						Nine Months Ended
	2018			2017			2018			2017				2018			2017			2018			2017
	(In Thousands)						(In Thousands)							(In Thousands)						(In Thousands)
OPERATING REVENUES
Electric		$494,605			$496,662			$1,045,629			$971,013				$568,399			$673,226			$1,614,028			$1,644,239

OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	106,496			50,691			214,802			150,100				164,438			133,254			379,240			283,354
Purchased power	64,839			74,552			136,811			129,685				58,213			63,423			195,024			193,108
Nuclear refueling outage expenses	19,159			17,335			42,561			36,954				19,062			22,988			61,623			59,942
Other operation and maintenance	177,792			168,190			347,150			331,198				188,882			171,498			536,032			502,696
Decommissioning	14,985			14,106			29,745			28,001				15,226			14,320			44,971			42,321
Taxes other than income taxes	24,445			25,128			52,350			49,179				27,972			29,259			80,322			78,438
Depreciation and amortization	72,701			69,087			144,682			136,153				73,579			70,433			218,261			206,586
Other regulatory charges (credits) - net	(12,313		)	4,948			(15,620		)	(5,578		)
Other regulatory credits - net														(13,758		)	(5,219		)	(29,378		)	(10,797		)
TOTAL	468,104			424,037			952,481			855,692				533,614			499,956			1,486,095			1,355,648

OPERATING INCOME	26,501			72,625			93,148			115,321				34,785			173,270			127,933			288,591

OTHER INCOME
Allowance for equity funds used during construction	4,471			5,432			8,479			9,782				3,735			4,140			12,214			13,922
Interest and investment income	2,478			14,195			9,292			21,127				12,060			6,738			21,352			27,865
Miscellaneous - net	(3,881		)	(3,688		)	(7,752		)	(6,644		)		(3,063		)	(3,332		)	(10,815		)	(9,976		)
TOTAL	3,068			15,939			10,019			24,265				12,732			7,546			22,751			31,811

INTEREST EXPENSE
Interest expense	30,917			28,514			60,683			55,766				31,632			31,010			92,315			86,776
Allowance for borrowed funds used during construction	(2,108		)	(2,552		)	(3,998		)	(4,514		)		(1,739		)	(1,944		)	(5,737		)	(6,458		)
TOTAL	28,809			25,962			56,685			51,252				29,893			29,066			86,578			80,318

INCOME BEFORE INCOME TAXES	760			62,602			46,482			88,334				17,624			151,750			64,106			240,084

Income taxes	(81,796		)	24,052			(72,329		)	35,480				(111,266		)	59,112			(183,595		)	94,592

NET INCOME	82,556			38,550			118,811			52,854				128,890			92,638			247,701			145,492

Preferred dividend requirements	357			357			714			714				357			357			1,071			1,071

EARNINGS APPLICABLE TO COMMON STOCK		$82,199			$38,193			$118,097			$52,140				$128,533			$92,281			$246,630			$144,421

See Notes to Financial Statements.

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ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2018 and 2017
(Unaudited)
2018 2017
(In Thousands)
OPERATING ACTIVITIES
Net income
$118,811

$52,854
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization 221,935
198,082
Deferred income taxes, investment tax credits, and non-current taxes accrued (32,906 ) 38,005
Changes in assets and liabilities:
Receivables (6,091 ) 12,092
Fuel inventory 12,289
(1,602 )
Accounts payable (25,035 ) (29,109 )
Taxes accrued 66,500
937
Interest accrued 1,260
1,816
Deferred fuel costs (5,896 ) (48,442 )
Other working capital accounts (8,750 ) (32,055 )
Provisions for estimated losses 12,453
7,457
Other regulatory assets 8,587
(5,592 )
Other regulatory liabilities (111,600 ) 24,890
Pension and other postretirement liabilities (37,601 ) (40,637 )
Other assets and liabilities 12,639
12,465
Net cash flow provided by operating activities 226,595
191,161

INVESTING ACTIVITIES
Construction expenditures (350,429 ) (381,197 )
Allowance for equity funds used during construction 8,732
10,198
Nuclear fuel purchases (23,342 ) (92,927 )
Proceeds from sale of nuclear fuel 30,907
51,029
Proceeds from nuclear decommissioning trust fund sales 121,440
167,329
Investment in nuclear decommissioning trust funds (128,598 ) (173,324 )
Change in money pool receivable - net (57,708 ) —
Changes in securitization account (279 ) 571
Insurance proceeds 7,043
—
Net cash flow used in investing activities (392,234 ) (418,321 )

FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt 464,544
222,937
Retirement of long-term debt (206,843 ) (6,799 )
Capital contribution from parent
350,000
—
Changes in short-term borrowings - net (49,974 ) 31,436
Changes in money pool payable - net (166,137 ) (37,563 )
Dividends paid:
Preferred stock (714 ) (714 )
Other 1,615
431
Net cash flow provided by financing activities 392,491
209,728

Net increase (decrease) in cash and cash equivalents 226,852
(17,432 )
Cash and cash equivalents at beginning of period 6,216
20,509
Cash and cash equivalents at end of period
$233,068

$3,077

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized
$56,900

$51,232

See Notes to Financial Statements.

ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
June 30, 2018 and December 31, 2017
(Unaudited)
2018 2017
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash
$239

$6,184
Temporary cash investments 232,829
32
Total cash and cash equivalents 233,068
6,216
Securitization recovery trust account 4,027
3,748
Accounts receivable:
Customer 108,351
110,016
Allowance for doubtful accounts (1,086 ) (1,063 )
Associated companies 93,367
38,765
Other 44,978
65,209
Accrued unbilled revenues 136,236
105,120
Total accounts receivable 381,846
318,047
Deferred fuel costs 69,099
63,302
Fuel inventory - at average cost 17,069
29,358
Materials and supplies - at average cost 193,849
192,853
Deferred nuclear refueling outage costs 61,618
56,485
Prepayments and other 22,112
12,108
TOTAL 982,688
682,117

OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds 954,400
944,890
Other 785
3,160
TOTAL 955,185
948,050

UTILITY PLANT
Electric 11,252,167
11,059,538
Construction work in progress 331,715
280,888
Nuclear fuel 219,762
277,345
TOTAL UTILITY PLANT 11,803,644
11,617,771
Less - accumulated depreciation and amortization 4,848,505
4,762,352
UTILITY PLANT - NET 6,955,139
6,855,419

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $21,480 as of June 30, 2018 and $28,583 as of December 31, 2017) 1,558,850
1,567,437
Deferred fuel costs 67,195
67,096
Other 16,263
13,910
TOTAL 1,642,308
1,648,443

TOTAL ASSETS
$10,535,320

$10,134,029

See Notes to Financial Statements.

ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2018 and December 31, 2017
(Unaudited)
2018 2017
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt
$41,700

$—
Short-term borrowings —
49,974
Accounts payable:
Associated companies 187,846
365,915
Other 174,639
215,942
Customer deposits 98,551
97,687
Taxes accrued 113,821
47,321
Interest accrued 19,475
18,215
Current portion of unprotected excess accumulated deferred income taxes 305,697
—
Other 34,052
29,922
TOTAL 975,781
824,976

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued 1,165,690
1,190,669
Accumulated deferred investment tax credits 33,503
34,104
Regulatory liability for income taxes - net 565,811
985,823
Other regulatory liabilities 366,306
363,591
Decommissioning 1,011,589
981,213
Accumulated provisions 47,182
34,729
Pension and other postretirement liabilities 315,711
353,274
Long-term debt (includes securitization bonds of $27,881 as of June 30, 2018 and $34,662 as of December 31, 2017) 3,170,724
2,952,399
Other 6,822
5,147
TOTAL 6,683,338
6,900,949

Commitments and Contingencies

Preferred stock without sinking fund 31,350
31,350

COMMON EQUITY
Common stock, $0.01 par value, authorized 325,000,000 shares; issued and outstanding 46,980,196 shares in 2018 and 2017 470
470
Paid-in capital 1,140,264
790,264
Retained earnings 1,704,117
1,586,020
TOTAL 2,844,851
2,376,754

TOTAL LIABILITIES AND EQUITY
$10,535,320

$10,134,029

See Notes to Financial Statements.

ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN COMMON EQUITY
For the Six Months Ended June 30, 2018 and 2017
(Unaudited)

Common Equity
Common
Stock Paid-in
Capital Retained
Earnings Total
(In Thousands)

Balance at December 31, 2016
$470

$790,243

$1,462,604

$2,253,317

Net income —
—
52,854
52,854
Preferred stock dividends —
—
(714 ) (714 )

Balance at June 30, 2017
$470

$790,243

$1,514,744

$2,305,457

Balance at December 31, 2017
$470

$790,264

$1,586,020

$2,376,754

Net income —
—
118,811
118,811
Capital contribution from parent —
350,000
—
350,000
Preferred stock dividends —
—
(714 ) (714 )

Balance at June 30, 2018
$470

$1,140,264

$1,704,117

$2,844,851

See Notes to Financial Statements.



ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2018 and 2017
(Unaudited)
	2018			2017
	(In Thousands)
OPERATING ACTIVITIES
Net income		$247,701			$145,492
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	335,939			311,725
Deferred income taxes, investment tax credits, and non-current taxes accrued	28,463			78,390
Changes in assets and liabilities:
Receivables	(33,422		)	(45,180		)
Fuel inventory	7,523			10,089
Accounts payable	(20,904		)	(78,396		)
Taxes accrued	30,686			15,367
Interest accrued	13,558			12,436
Deferred fuel costs	24,463			(53,664		)
Other working capital accounts	(8,827		)	(6,762		)
Provisions for estimated losses	10,013			10,094
Other regulatory assets	22,574			(4,680		)
Other regulatory liabilities	(218,518		)	43,473
Pension and other postretirement liabilities	(64,461		)	(73,107		)
Other assets and liabilities	(12,203		)	2,274
Net cash flow provided by operating activities	362,585			367,551

INVESTING ACTIVITIES
Construction expenditures	(517,882		)	(558,985		)
Allowance for equity funds used during construction	12,572			14,521
Nuclear fuel purchases	(79,142		)	(95,289		)
Proceeds from sale of nuclear fuel	31,897			51,029
Proceeds from nuclear decommissioning trust fund sales	259,331			219,223
Investment in nuclear decommissioning trust funds	(269,913		)	(228,740		)
Change in money pool receivable - net	(13,421		)	—
Changes in securitization account	(4,821		)	(3,619		)
Insurance proceeds	7,043			—
Change in other investments	(1		)	(65,981		)
Net cash flow used in investing activities	(574,337		)	(667,841		)

FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	658,427			222,717
Retirement of long-term debt	(372,447		)	(6,803		)
Capital contribution from parent	350,000			—
Changes in short-term borrowings - net	(49,974		)	23,257
Changes in money pool payable - net	(166,137		)	43,882
Dividends paid:
Preferred stock	(1,071		)	(1,071		)
Other	8,520			(1,737		)
Net cash flow provided by financing activities	427,318			280,245

Net increase (decrease) in cash and cash equivalents	215,566			(20,045		)
Cash and cash equivalents at beginning of period	6,216			20,509
Cash and cash equivalents at end of period		$221,782			$464

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized		$74,966			$70,321

See Notes to Financial Statements.



ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2018 and December 31, 2017
(Unaudited)
	2018			2017
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash		$13,121			$6,184
Temporary cash investments	208,661			32
Total cash and cash equivalents	221,782			6,216
Securitization recovery trust account	8,570			3,748
Accounts receivable:
Customer	141,294			110,016
Allowance for doubtful accounts	(1,420		)	(1,063		)
Associated companies	57,253			38,765
Other	51,756			65,209
Accrued unbilled revenues	116,007			105,120
Total accounts receivable	364,890			318,047
Deferred fuel costs	38,691			63,302
Fuel inventory - at average cost	21,835			29,358
Materials and supplies - at average cost	196,623			192,853
Deferred nuclear refueling outage costs	57,683			56,485
Prepayments and other	22,316			12,108
TOTAL	932,390			682,117

OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	996,857			944,890
Other	785			3,160
TOTAL	997,642			948,050

UTILITY PLANT
Electric	11,376,058			11,059,538
Construction work in progress	350,554			280,888
Nuclear fuel	240,582			277,345
TOTAL UTILITY PLANT	11,967,194			11,617,771
Less - accumulated depreciation and amortization	4,908,917			4,762,352
UTILITY PLANT - NET	7,058,277			6,855,419

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $17,247 as of September 30, 2018 and $28,583 as of December 31, 2017)	1,544,863			1,567,437
Deferred fuel costs	67,244			67,096
Other	18,252			13,910
TOTAL	1,630,359			1,648,443

TOTAL ASSETS		$10,618,668			$10,134,029

See Notes to Financial Statements.



ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2018 and December 31, 2017
(Unaudited)
	2018		2017
	(In Thousands)
CURRENT LIABILITIES
Short-term borrowings		$—		$49,974
Accounts payable:
Associated companies	183,372		365,915
Other	172,820		215,942
Customer deposits	99,138		97,687
Taxes accrued	78,007		47,321
Interest accrued	31,773		18,215
Current portion of unprotected excess accumulated deferred income taxes	179,712		—
Other	32,411		29,922
TOTAL	777,233		824,976

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	1,235,625		1,190,669
Accumulated deferred investment tax credits	33,203		34,104
Regulatory liability for income taxes - net	533,179		985,823
Other regulatory liabilities	418,005		363,591
Decommissioning	1,026,816		981,213
Accumulated provisions	44,742		34,729
Pension and other postretirement liabilities	288,870		353,274
Long-term debt (includes securitization bonds of $27,958 as of September 30, 2018 and $34,662 as of December 31, 2017)	3,242,282		2,952,399
Other	13,979		5,147
TOTAL	6,836,701		6,900,949

Commitments and Contingencies

Preferred stock without sinking fund	31,350		31,350

COMMON EQUITY
Common stock, $0.01 par value, authorized 325,000,000 shares; issued and outstanding 46,980,196 shares in 2018 and 2017	470		470
Paid-in capital	1,140,264		790,264
Retained earnings	1,832,650		1,586,020
TOTAL	2,973,384		2,376,754

TOTAL LIABILITIES AND EQUITY		$10,618,668		$10,134,029

See Notes to Financial Statements.

ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
SELECTED OPERATING RESULTS
For the Three and Six Months Ended June 30, 2018 and 2017
(Unaudited)

Three Months Ended Increase/
Description 2018 2017 (Decrease) %

(Dollars In Millions)
Electric Operating Revenues:
Residential
$159

$160

($1 ) (1 )
Commercial 94
119
(25 ) (21 )
Industrial 98
114
(16 ) (14 )
Governmental 4
5
(1 ) (20 )
Total billed retail 355
398
(43 ) (11 )
Sales for resale:
Associated companies 26
31
(5 ) (16 )
Non-associated companies 27
6
21
350
Other 87
62
25
40
Total
$495

$497

($2 ) —

Billed Electric Energy Sales (GWh):
Residential 1,644
1,462
182
12
Commercial 1,396
1,372
24
2
Industrial 1,953
1,829
124
7
Governmental 58
57
1
2
Total retail 5,051
4,720
331
7
Sales for resale:
Associated companies 236
387
(151 ) (39 )
Non-associated companies 1,171
386
785
203
Total 6,458
5,493
965
18

Six Months Ended Increase/
Description 2018 2017 (Decrease) %
(Dollars In Millions)
Electric Operating Revenues:
Residential
$395

$343

$52
15
Commercial 214
225
(11 ) (5 )
Industrial 210
210
—
—
Governmental 8
9
(1 ) (11 )
Total billed retail 827
787
40
5
Sales for resale:
Associated companies 56
63
(7 ) (11 )
Non-associated companies 63
51
12
24
Other 100
70
30
43
Total
$1,046

$971

$75
8

Billed Electric Energy Sales (GWh):
Residential 3,973
3,389
584
17
Commercial 2,761
2,687
74
3
Industrial 3,781
3,510
271
8
Governmental 114
113
1
1
Total retail 10,629
9,699
930
10
Sales for resale:
Associated companies 723
833
(110 ) (13 )
Non-associated companies 2,888
2,348
540
23
Total 14,240
12,880
1,360
11



ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN COMMON EQUITY
For the Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Common Equity
	Common Stock		Paid-in Capital		Retained Earnings			Total
	(In Thousands)

Balance at December 31, 2016		$470		$790,243		$1,462,604			$2,253,317

Net income	—		—		145,492			145,492
Preferred stock dividends	—		—		(1,071		)	(1,071		)

Balance at September 30, 2017		$470		$790,243		$1,607,025			$2,397,738


Balance at December 31, 2017		$470		$790,264		$1,586,020			$2,376,754

Net income	—		—		247,701			247,701
Capital contribution from parent	—		350,000		—			350,000
Preferred stock dividends	—		—		(1,071		)	(1,071		)

Balance at September 30, 2018		$470		$1,140,264		$1,832,650			$2,973,384

See Notes to Financial Statements.



ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Three Months Ended				Increase/
Description	2018		2017		(Decrease)			%
	(Dollars In Millions)
Electric Operating Revenues:
Residential		$250		$254		($4	)	(2	)
Commercial	120		150		(30		)	(20	)
Industrial	126		145		(19		)	(13	)
Governmental	4		6		(2		)	(33	)
Total billed retail	500		555		(55		)	(10	)
Sales for resale:
Associated companies	23		33		(10		)	(30	)
Non-associated companies	37		45		(8		)	(18	)
Other	8		40		(32		)	(80	)
Total		$568		$673		($105	)	(16	)

Billed Electric Energy Sales (GWh):
Residential	2,482		2,236		246			11
Commercial	1,816		1,723		93			5
Industrial	2,283		2,074		209			10
Governmental	67		67		—			—
Total retail	6,648		6,100		548			9
Sales for resale:
Associated companies	483		483		—			—
Non-associated companies	1,818		2,026		(208		)	(10	)
Total	8,949		8,609		340			4

	Nine Months Ended				Increase/
Description	2018		2017		(Decrease)			%
	(Dollars In Millions)
Electric Operating Revenues:
Residential		$645		$597		$48		8
Commercial	334		375		(41		)	(11	)
Industrial	335		355		(20		)	(6	)
Governmental	13		15		(2		)	(13	)
Total billed retail	1,327		1,342		(15		)	(1	)
Sales for resale:
Associated companies	80		96		(16		)	(17	)
Non-associated companies	100		96		4			4
Other	107		110		(3		)	(3	)
Total		$1,614		$1,644		($30	)	(2	)

Billed Electric Energy Sales (GWh):
Residential	6,455		5,625		830			15
Commercial	4,577		4,410		167			4
Industrial	6,064		5,584		480			9
Governmental	181		180		1			1
Total retail	17,277		15,799		1,478			9
Sales for resale:
Associated companies	1,206		1,316		(110		)	(8	)
Non-associated companies	4,706		4,374		332			8
Total	23,189		21,489		1,700			8

ENTERGY LOUISIANA, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter 2017

Net income increased ~~$59.9~~$32 million primarily due to a lower effective income tax rate primarily due to an IRS audit settlement for the 2012-2013 tax returns that is discussed in Note 10 to the financial statements herein. The increase in income is partially offset by higher other operation and maintenance expenses.

~~Six Months Ended June 30, 2018 Compared to Six Months Ended June 30, 2017~~

Net income increased $77.1 million primarily due to a lower effective income tax rate, primarily due to an IRS audit settlement for the 2012-2013 tax returns that is discussed in Note 10 to the financial statements herein, and higher net revenue, after excluding the effect of the return of unprotected excess accumulated deferred income taxes to customers which is offset in income taxes. The increase was partially offset by higher other operation and maintenance expenses and higher depreciation and amortization expenses.

Nine Months Ended September 30, 2018 Compared to Nine Months Ended September 30, 2017

Net income increased $109.1 million primarily due to higher net revenue, after excluding the effect of the return of unprotected excess accumulated deferred income taxes to customers which is offset in income taxes, and a lower effective income tax rate. The increase was partially offset by higher other operation and maintenance expenses and higher depreciation and amortization expenses.

Net Revenue

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter 2017



	Amount
	(In Millions)
2017 net revenue		$717.4
Return of unprotected excess accumulated deferred income taxes to customers	(54.8		)
Retail electric price	(12.6		)
Volume/weather	14.7
Other	6.3
2018 net revenue		$671.0

The return of unprotected excess accumulated deferred income taxes to customers resulted from the return of unprotected excess accumulated deferred income taxes through changes in the formula rate plan, effective May 2018. There is no effect on net income as the reduction in net revenue was offset by a reduction in income tax expense. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

The retail electric price variance is primarily due to regulatory charges of $18.3 million recorded in the third quarter 2018 to reflect the effects of a provision in the settlement reached in the formula rate plan extension proceeding to return the benefits of the lower federal income tax rate in 2018 to customers and a decrease in formula rate plan revenues implemented with the first billing cycle of September 2017. The decrease was partially offset by an increase

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Management's Financial Discussion and Analysis

resulting from lower Grand Gulf purchased power expenses. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan extension proceeding.

The volume/weather variance is primarily due to the effect of more favorable weather on residential and commercial sales.

Nine Months Ended September 30, 2018 Compared to Nine Months Ended September 30, 2017

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges (credits). Following is an analysis of the change in net revenue comparing the ~~second quarter~~nine months ended September 30, 2018 to the ~~second quarter~~nine months ended September 30, 2017:



	Amount
	(In Millions)
2017 net revenue		$~~623.2~~1,901.7
Return of unprotected excess accumulated deferred income taxes to customers	(~~31.5~~86.3		)
Retail electric price	(~~20.1~~52.7		)
Volume/weather	~~26.1~~65.1
Other	~~(1.1~~13.4		)
2018 net revenue		$~~596.6~~1,841.2

The return of unprotected excess accumulated deferred income taxes to customers resulted from the return ~~in the second quarter 2018~~ of unprotected excess accumulated deferred income taxes through changes in the formula rate plan, effective May 2018. There is no effect on net income as the reduction in net revenue was offset by a reduction in income tax expense. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

The retail electric price variance is primarily due to a regulatory charge of $27.4 million recorded in second quarter 2018 to reflect the effects of a provision in the settlement reached in the formula rate plan extension proceeding to return the benefits of the lower federal income tax rate in 2018 to customers. Partially offsetting the decrease were increases resulting from an energy efficiency rider effective January 2018, lower Grand Gulf purchased power expenses,

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~~Management's Financial Discussion and Analysis~~

and a decrease in the storm cost offset rider effective April 2018 for financing of storm costs for Hurricane Gustav and Hurricane Ike. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan extension proceeding.

The volume/weather variance is primarily due to the effect of more favorable weather on residential and commercial sales. The increase was partially offset by a decrease in industrial usage primarily due to decreased demand from cogeneration customers.

~~Six Months Ended June 30, 2018 Compared to Six Months Ended June 30, 2017~~

~~Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other~~ regulatory charges ~~(credits). Following is an analysis~~ of ~~the change in net revenue comparing the six months ended June 30, 2018 to the six months ended June 30, 2017:~~



	~~Amount~~
	~~(In Millions)~~
~~2017 net revenue~~		~~$1,184.3~~
~~Retail electric price~~	~~(40.2~~		)
~~Return of unprotected excess accumulated deferred income taxes to customers~~	~~(31.5~~		)
~~Volume/weather~~	~~50.3~~
~~Other~~	~~7.3~~
~~2018 net revenue~~		~~$1,170.2~~

~~The retail electric price variance is primarily due to a regulatory charge of $55~~$73.3 million recorded in 2018 to reflect the effects of a provision in the settlement reached in the formula rate plan extension proceeding to return the benefits of the lower federal income tax rate in 2018 to customers. Partially offsetting the decrease were increases resulting from ~~an energy efficiency rider effective January 2018,~~ lower Grand Gulf purchased power expenses and ~~a decrease in the storm cost offset~~an energy efficiency rider, effective ~~April 2018 for financing of storm costs for Hurricane Gustav and Hurricane Ike.~~January 2018. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan extension proceeding.

The return of unprotected excess accumulated deferred income taxes to customers resulted from the return in 2018 of unprotected excess accumulated deferred income taxes through changes in the formula rate plan, effective May 2018. There is no effect on net income as the reduction in net revenue was offset by a reduction in income tax expense. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

~~The~~ volume/weather variance is primarily due to an increase of ~~746~~1,257 GWh, or 3%, in billed electricity usage, including the effect of more favorable weather on residential and commercial sales. The increase was partially offset by a decrease in industrial usage primarily due to a decrease in demand from existing customers.

Other Income Statement Variances

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter 2017

Other operation and maintenance expenses increased primarily due to to:

an increase of ~~$12~~$3.6 million in fossil-fueled generation expenses primarily due to an overall higher scope of work performed ~~during plant outages~~ in the third quarter 2018 as compared to the same period in ~~2017 and~~ 2017;

an increase of ~~$3.8~~$3.1 million in ~~loss provisions.~~

~~Depreciation and amortization~~information technology expenses ~~increased~~ primarily due to ~~additions to plant~~higher software maintenance costs and higher contract costs;

a $1.7 million loss on disposal of assets in ~~service.~~2018 and a $1.4 million gain on disposal of assets in 2017; and

an increase of $2.5 million in energy efficiency costs.

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Management's Financial Discussion and Analysis

~~Six~~

The increase was partially offset by a decrease of $4.8 million in nuclear generation expenses primarily due to a lower scope of work performed in the third quarter 2018 as compared to the same period in 2017.

Depreciation and amortization expenses increased primarily due to additions to plant in service.

Other income increased primarily due to an increase in the allowance for equity funds used during construction due to higher construction work in progress in 2018, which included the Lake Charles Power Station and St. Charles Power Station projects. The increase was partially offset due to a change in decommissioning trust fund investment activity, including portfolio rebalancing of certain of the decommissioning trust funds in 2017.

Nine Months Ended ~~June~~September 30, 2018 Compared to ~~Six~~Nine Months Ended ~~June~~September 30, 2017

Other operation and maintenance expenses increased primarily due to:

an increase of ~~$19.1~~$21.8 million in fossil-fueled generation expenses primarily due to an overall higher scope of work performed ~~during plant outages~~ in 2018 as compared to the same period in 2017;

an increase of $6.8 million in energy efficiency costs;

an increase of $6.8 million in transmission expenses primarily due to higher labor and contract costs to support industrial customers;

an increase of $6.4 million in information technology expenses primarily due to higher software maintenance costs and higher contract costs; and

an increase of ~~$10.6~~$5.5 million in nuclear generation expenses primarily due to higher nuclear labor costs, including contract labor, to position the nuclear fleet to meet its operational goals and a higher scope of work performed during plant outages in 2018 as compared to the same period in 2017.

The increase was partially offset by higher nuclear insurance refunds of $4.2 million in 2018.

Taxes other than income taxes increased primarily due to increases in ad valorem taxes ~~local franchise taxes, and payroll taxes. Ad valorem taxes increased primarily due to~~resulting from higher assessments. ~~Local franchise taxes increased primarily due to higher revenues in 2018 as compared to the same period in 2017.~~

Depreciation and amortization expenses increased primarily due to additions to plant in service.

Other income increased primarily due to an increase in the allowance for equity funds used during construction due to higher construction work in progress in 2018, which included the Lake Charles Power Station and St. Charles Power Station ~~project, and changes~~projects. The increase was partially offset by a change in decommissioning trust fund investment activity, including portfolio rebalancing of certain of the decommissioning trust funds in 2017.

Income Taxes

The effective income tax ~~rates were (42.7%)~~rate was 1.3% for the ~~second~~third quarter ~~2018 and (12.7%) for the six months ended June 30,~~ 2018. The ~~differences~~difference in the effective income tax ~~rates~~rate for the ~~second~~third quarter ~~2018 and the six months ended June 30,~~ 2018 versus the federal statutory rate of 21% ~~were~~was primarily due to ~~an IRS audit settlement for~~ the ~~2012-2013 tax returns,~~ amortization of excess accumulated deferred income taxes and book and tax differences related to the non-taxable income distributions earned on preferred membership interests, ~~certain book and tax differences related to utility plant items, and book and tax differences related to the allowance for equity funds used during construction,~~ partially offset by state income taxes. See Notes 2 and 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was (6.3%) for the nine months ended September 30, 2018. The difference in the effective income tax rate for the nine months ended September 30, 2018 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, an IRS audit settlement for the 2012-2013 tax returns, and book and tax differences related to the non-taxable income distributions earned on preferred membership interests, partially offset by state income taxes. See Notes 2 and 10 to the financial statements herein and

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Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 10 to the financial statements herein for a discussion of the IRS audit settlement.

The effective income tax ~~rates were 31.3%~~rate was 33.6% for the ~~second~~third quarter ~~2017 and 31.3% for the six months ended June 30,~~ 2017. The ~~differences~~difference in the effective income tax ~~rates~~rate for the ~~second~~third quarter 2017 versus the federal statutory rate of 35% was primarily due to book and tax differences related to the ~~six~~non-taxable income distributions earned on preferred membership interests and book and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes.

The effective income tax rate was 32.4% for the nine months ended ~~June~~September 30, 2017. The difference in the nine months ended September 30, 2017 versus the federal statutory rate of 35% ~~were~~was primarily due to book and tax differences related to the non-taxable income distributions earned on preferred membership interests and book and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes.

Income Tax Legislation

See the “Income Tax Legislation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for a discussion of the Tax Cuts and Jobs Act, the federal income tax legislation enacted in December 2017. Note 3 to the financial statements in the Form 10-K contains additional discussion of the effect of the Tax Act on 2017 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act. Note 10 to the financial statements herein contains updates to that discussion. Note 2 to the financial statements herein and in the Form 10-K contains a discussion of proceedings commenced or other responses by Entergy and Entergy’s regulators to the Tax Act.

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Liquidity and Capital Resources

Cash Flow

Cash flows for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017 were as follows:


	2018			2017			2018			2017
	(In Thousands)						(In Thousands)
Cash and cash equivalents at beginning of period		$35,907			$213,850			$35,907			$213,850

Cash flow provided by (used in):
Operating activities	583,192			533,755			943,300			927,176
Investing activities	(838,202		)	(900,210		)	(1,283,844		)	(1,379,365		)
Financing activities	248,131			367,888			518,222			293,862
Net increase (decrease) in cash and cash equivalents	(6,879		)	1,433			177,678			(158,327		)

Cash and cash equivalents at end of period		$29,028			$215,283			$213,585			$55,523

Operating Activities

Net cash flow provided by operating activities increased ~~$49.4~~$16.1 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to:

a decrease of $78.7 million in spending on nuclear refueling outages; and

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~~a decrease of $63.1 million in spending on nuclear refueling outages.~~Management's Financial Discussion and Analysis

The increase was partially offset by:

a decrease of $114 million in income tax refunds in 2018 as compared to the same period in 2017. Entergy Louisiana received income tax refunds in 2017 in accordance with an intercompany income tax allocation agreement resulting from the utilization of Entergy Louisiana’s net operating losses; and

the return of unprotected excess accumulated deferred income taxes to customers. See Note 2 to the financial statements herein for a discussion of the regulatory activity regarding the Tax Cuts and Jobs ~~Act; and~~

~~a decrease due to the timing of recovery of fuel and purchased power costs.~~Act.

Investing Activities

Net cash flow used in investing activities decreased ~~$62~~$95.5 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to:

a decrease of ~~$148.9~~$152.5 million as a result of fluctuations in nuclear fuel activity because of variations from year to year in the timing and pricing of fuel reload requirements in the Utility business, material and service deliveries, and the timing of cash payments during the nuclear fuel cycle;

money pool activity; ~~and~~

$33.3 million in funds held on deposit in 2017 for interest payments due October 1, 2017;

a decrease of ~~$23.3~~$14.1 million in nuclear construction expenditures primarily due to decreased spending on various nuclear ~~projects.~~projects; and

a decrease of $8.9 million in information technology construction expenditures primarily due to higher spending in 2017 on various information technology projects and upgrades.

The decrease was partially offset by by:

an increase of ~~$87~~$89.9 million in fossil-fueled generation construction expenditures primarily due to higher spending on the Lake Charles Power Station project in 2018, partially offset by lower spending on the St. Charles Power Station project in 2018; and

an increase of ~~$65.5~~$80 million

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in transmission construction expenditures primarily due to a higher scope of work performed in 2018 as compared to the same period in 2017.

~~Decreases~~Increases in Entergy Louisiana’s receivable from the money pool are a ~~source~~use of cash flow, and Entergy Louisiana’s receivable from the money pool ~~decreased~~increased by ~~$4.4~~$2.4 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to increasing by ~~$33~~$50.4 million for the ~~six~~nine months ended ~~June~~September 30, 2017. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Net cash flow provided by financing activities ~~decreased $119.8~~increased $224.4 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to:

the issuance of $750 million of 4.00% Series first mortgage bonds in March 2018. A portion of the proceeds was used to repay $375 million of 6.0% Series first mortgage bonds in May 2018;

the issuance of $600 million of 4.20% collateral trust mortgage bonds in August 2018. A portion of the proceeds was used to repay $300 million of 6.5% Series first mortgage bonds in September 2018; and

a decrease of $35.3 million in common equity distributions.

The increase was partially offset by:

the issuance of $450 million of 3.12% collateral trust mortgage bonds in May 2017. A portion of the proceeds was used to repay $45.3 million of Waterford Series collateral trust mortgage notes;

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net repayments of short-term borrowings of $43.5 million on the nuclear fuel company variable interest entities’ credit facilities in 2018 compared to net short-term borrowings of ~~$30.7~~$36.8 million in 2017; and

net repayments of long-term borrowings of ~~$11.8~~$37 million on the nuclear fuel company variable interest entities’ credit facilities in 2018 compared to net long-term borrowings of ~~$51.9~~$115.1 million in 2017.

~~The decrease was partially offset by:~~

~~the issuance of $750 million of 4.00% Series first mortgage bonds in March 2018. A portion of the proceeds was used to repay $375 million of 6.0% Series First Mortgage bonds in May 2018; and~~

~~a decrease of $35.3 million in common equity distributions.~~

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

Capital Structure

Entergy Louisiana’s debt to capital ratio is shown in the following table.


	June 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Debt to capital	53.9	%	53.8	%	54.0	%	53.8	%
Effect of excluding securitization bonds	(0.2	%)	(0.3	%)	(0.3	%)	(0.3	%)
Debt to capital, excluding securitization bonds (a)	53.7	%	53.5	%	53.7	%	53.5	%
Effect of subtracting cash	(0.1	%)	(0.1	%)	(0.8	%)	(0.1	%)
Net debt to net capital, excluding securitization bonds (a)	53.6	%	53.4	%	52.9	%	53.4	%


(a)	Calculation excludes the securitization bonds, which are non-recourse to Entergy Louisiana.

Net debt consists of debt less cash and cash equivalents. Debt consists of short-term borrowings and long-term debt, including the currently maturing portion. Capital consists of debt and common equity. Net capital consists of capital less cash and cash equivalents. Entergy Louisiana uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy Louisiana’s financial condition because the securitization bonds are non-recourse to Entergy Louisiana, as more fully described in Note 5 to the financial statements in the Form 10-K. Entergy Louisiana also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Louisiana’s financial condition because net debt indicates Entergy Louisiana’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

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Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Louisiana’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

Entergy Louisiana is developing its capital investment plan for 2019 through 2021 and currently anticipates making $4.1 billion in capital investments during that period. The preliminary estimate includes amounts associated with specific investments, such as the Washington Parish Energy Center, discussed below, and the St. Charles Power Station and the Lake Charles Power Station; transmission projects to enhance reliability, reduce congestion, and enable economic growth; distribution spending to enhance reliability and improve service to customers, including advanced meters and related investments; resource planning, including potential generation projects; system improvements; investments in River Bend and Waterford 3; software and security; and other investments. Estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints and requirements, environmental compliance, business opportunities, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital.

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Entergy Louisiana’s receivables from the money pool were as follows:

June 30,
2018

December 31,
2017

June 30,
2017

December 31,
2016
(In Thousands)
$6,779 $11,173 $55,542 $22,503

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy Louisiana has a credit facility in the amount of $350 million scheduled to expire in ~~August 2022.~~September 2023. The credit facility includes fronting commitments for the issuance of letters of credit against $15 million of the borrowing capacity of the facility. As of ~~June~~September 30, 2018, there were no cash borrowings and ~~$9.1 million of~~no letters of credit outstanding under the credit facility. In addition, Entergy Louisiana is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of ~~June~~September 30, 2018, a ~~$37.8~~$22 million letter of credit was outstanding under Entergy Louisiana’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

The Entergy Louisiana nuclear fuel company variable interest entities have two separate credit facilities, ~~one~~each in the amount of $105 million and ~~one in the amount of $85 million, both~~ scheduled to expire in ~~May 2019.~~September 2021. As of ~~June~~September 30, 2018, ~~$44.8~~$34.5 million in loans were outstanding under the credit facility for the Entergy Louisiana River Bend nuclear fuel company variable interest entity. As of ~~June~~September 30, 2018, ~~$45.4~~$30.5 million in loans were outstanding under the credit facility for the Entergy Louisiana Waterford nuclear fuel company variable interest entity. See Note 4 to the financial statements herein for additional discussion of the nuclear fuel company variable interest entity credit facilities.

Washington Parish Energy Center

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – State and Local Rate Regulation and Fuel Cost Recovery” in the Form 10-K for a discussion of state and local rate regulation and fuel cost recovery. The following are updates to that discussion.

Fuel and purchased power cost recovery

In July 2014 the LPSC authorized its staff to initiate an audit of the fuel adjustment clause filings by Entergy Gulf States Louisiana, whose business was combined with Entergy Louisiana in 2015. The audit includes a review of the reasonableness of charges flowed through Entergy Gulf States Louisiana’s fuel adjustment clause for the period from 2010 through 2013. Discovery commenced in July 2015. No report of audit has been issued.

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Retail Rates - Electric

2016 Formula Rate Plan Filing

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were required but reserved for several issues, including Entergy Louisiana’s September 2017 update to its formula rate plan evaluation report. In July 2018, Entergy Louisiana and the LPSC staff filed an unopposed joint report setting forth a correction to the annualization calculation, the effect of which was a net $3.5 million revenue requirement reduction, and indicating that there are no outstanding issues with the 2016 formula rate plan report, the supplemental report, or the interim updates. ~~The~~In September 2018 the LPSC ~~voted to accept and approve~~approved the unopposed joint ~~report in August 2018.~~report.

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 target earned return on common equity;

a framework for the flow back of certain tax benefits created by the Tax Act to customers; 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.

2017 Formula Rate Plan Filing

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adjustments to the additional capacity and MISO cost recovery mechanisms of the formula rate plan, and implementation of the transmission recovery mechanism. In August 2018, Entergy Louisiana filed a supplemental formula rate plan evaluation report to reflect changes from the 2016 test year formula rate plan proceedings, a decrease to the transmission recovery mechanism to reflect lower actual capital additions, and a decrease to evaluation period expenses to reflect the terms of a new power sales agreement. Based on the August 2018 update, Entergy Louisiana would recognize a total decrease in formula rate plan revenue of approximately $17.6 million. Results of the updated 2017 evaluation report filing ~~will be~~were implemented with the September 2018 billing ~~month.~~month subject to refund and review by the LPSC staff and intervenors. In accordance with the terms of the formula rate plan, in September 2018 the LPSC staff and intervenors submitted their responses to Entergy Louisiana’s original formula rate plan evaluation report and supplemental compliance updates. The LPSC staff asserted objections/reservations regarding 1) Entergy Louisiana’s proposed rate adjustments associated with the return of excess accumulated deferred income taxes pursuant to the Tax Act and the treatment of accumulated deferred income taxes related to reductions of rate base; 2) Entergy Louisiana’s reservation regarding treatment of a regulatory asset related to certain special orders by the LPSC; and 3) test year expenses billed from Entergy Services to Entergy Louisiana. Intervenors also objected to Entergy Louisiana’s treatment of the regulatory asset related to certain special orders by the LPSC. A procedural schedule has not yet been established to resolve these issues.

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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. Entergy Louisiana submitted a compliance filing regarding retirement of Willow Glen 2 and 4, and the LPSC closed the proceeding.

Retail Rates - Gas

2017 Rate Stabilization Plan Filing

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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%. As-filed rates from the supplemental filing were implemented, subject to refund, with customers receiving 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 reduction in the gas infrastructure rider effective with bills rendered on and after the first billing cycle of July 2018. The proceeding is currently in its discovery phase. A procedural schedule has not been established.

Industrial and Commercial Customers

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Industrial and Commercial Customers” in the Form 10-K for a discussion of industrial and commercial customers.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation.

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for a discussion of nuclear matters.

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Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Louisiana’s accounting for nuclear decommissioning costs, utility regulatory accounting, unbilled revenue, impairment of long-lived assets and trust fund investments, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies. The following is an update to that discussion.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of new accounting pronouncements.

																										ENTERGY LOUISIANA, LLC AND SUBSIDIARIES	CONSOLIDATED INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2018 and 2017
For the Three and Nine Months Ended September 30, 2018 and 2017													For the Three and Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Three Months Ended						Six Months Ended							Three Months Ended						Nine Months Ended
	2018			2017			2018			2017				2018			2017			2018			2017
	(In Thousands)						(In Thousands)							(In Thousands)						(In Thousands)
OPERATING REVENUES
Electric		$1,061,689			$1,072,126			$2,066,795			$1,936,202				$1,196,278			$1,280,475			$3,263,073			$3,216,677
Natural gas	11,099			11,308			35,337			28,015				10,334			10,019			45,671			38,034
TOTAL	1,072,788			1,083,434			2,102,132			1,964,217				1,206,612			1,290,494			3,308,744			3,254,711

OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	200,528			180,056			381,309			334,100				318,987			301,584			700,296			635,684
Purchased power	266,614			282,673			518,386			522,500				218,063			273,325			736,449			795,825
Nuclear refueling outage expenses	12,671			12,764			25,770			24,949				12,969			13,616			38,739			38,565
Other operation and maintenance	250,994			236,978			485,374			454,090				239,230			229,664			724,604			683,754
Decommissioning	13,480			12,283			26,252			24,406				13,654			12,444			39,906			36,850
Taxes other than income taxes	47,147			45,076			98,427			90,359				44,594			45,059			143,021			135,418
Depreciation and amortization	122,177			116,107			242,920			231,737				124,030			117,923			366,950			349,660
Other regulatory charges (credits) - net	9,017			(2,521		)	32,214			(76,708		)		(1,433		)	(1,795		)	30,781			(78,503		)
TOTAL	922,628			883,416			1,810,652			1,605,433				970,094			991,820			2,780,746			2,597,253

OPERATING INCOME	150,160			200,018			291,480			358,784				236,518			298,674			527,998			657,458

OTHER INCOME
Allowance for equity funds used during construction	19,124			11,109			36,869			21,099				20,423			13,393			57,292			34,492
Interest and investment income	46,853			41,919			90,128			81,749				53,009			42,662			143,137			124,411
Miscellaneous - net	(22,770		)	(8,889		)	(30,435		)	(18,031		)		(25,782		)	(11,542		)	(56,217		)	(29,573		)
TOTAL	43,207			44,139			96,562			84,817				47,650			44,513			144,212			129,330

INTEREST EXPENSE
Interest expense	73,582			68,483			143,678			135,798				73,084			69,518			216,762			205,316
Allowance for borrowed funds used during construction	(9,451		)	(5,541		)	(18,214		)	(10,715		)		(10,168		)	(6,713		)	(28,382		)	(17,428		)
TOTAL	64,131			62,942			125,464			125,083				62,916			62,805			188,380			187,888

INCOME BEFORE INCOME TAXES	129,236			181,215			262,578			318,518				221,252			280,382			483,830			598,900

Income taxes	(55,122		)	56,736			(33,374		)	99,661				2,944			94,098			(30,430		)	193,759

NET INCOME		$184,358			$124,479			$295,952			$218,857				$218,308			$186,284			$514,260			$405,141

See Notes to Financial Statements.

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																									ENTERGY LOUISIANA, LLC AND SUBSIDIARIES	CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Six Months Ended June 30, 2018 and 2017
For the Three and Nine Months Ended September 30, 2018 and 2017													For the Three and Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Three Months Ended						Six Months Ended						Three Months Ended						Nine Months Ended
	2018			2017			2018			2017			2018			2017			2018			2017
	(In Thousands)						(In Thousands)						(In Thousands)						(In Thousands)

Net Income		$184,358			$124,479			$295,952			$218,857			$218,308			$186,284			$514,260			$405,141
Other comprehensive loss
Pension and other postretirement liabilities (net of tax benefit of $177, $292, $353, and $524)	(501		)	(310		)	(1,002		)	(680		)
Pension and other postretirement liabilities (net of tax benefit of $177, $232, $530, and $756)													(500		)	(370		)	(1,502		)	(1,050		)
Other comprehensive loss	(501		)	(310		)	(1,002		)	(680		)	(500		)	(370		)	(1,502		)	(1,050		)
Comprehensive Income		$183,857			$124,169			$294,950			$218,177			$217,808			$185,914			$512,758			$404,091

See Notes to Financial Statements.

														ENTERGY LOUISIANA, LLC AND SUBSIDIARIES	CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2018 and 2017
For the Nine Months Ended September 30, 2018 and 2017							For the Nine Months Ended September 30, 2018 and 2017
(Unaudited)
	2018			2017				2018			2017
	(In Thousands)							(In Thousands)
OPERATING ACTIVITIES
Net income		$295,952			$218,857				$514,260			$405,141
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	323,188			300,805				490,638			458,963
Deferred income taxes, investment tax credits, and non-current taxes accrued	119,378			220,492				167,603			303,397
Changes in working capital:
Receivables	(23,815		)	950				(61,281		)	(92,610		)
Fuel inventory	(2,581		)	4,534				6,120			7,643
Accounts payable	17,324			42,079				(20,481		)	31,865
Prepaid taxes and taxes accrued	(56,076		)	52,686				(22,893		)	97,138
Interest accrued	790			(2,883		)		2,382			9,149
Deferred fuel costs	(68,741		)	(74,113		)		(25,781		)	(37,753		)
Other working capital accounts	(6,053		)	(61,515		)		(5,086		)	(49,266		)
Changes in provisions for estimated losses	5,803			(6,108		)		7,800			(6,331		)
Changes in other regulatory assets	42,203			39,711				49,245			60,014
Changes in other regulatory liabilities	(8,811		)	(64,293		)		(29,943		)	(72,060		)
Changes in pension and other postretirement liabilities	(32,970		)	(38,175		)		(59,305		)	(70,489		)
Other	(22,399		)	(99,272		)		(69,978		)	(117,625		)
Net cash flow provided by operating activities	583,192			533,755				943,300			927,176

INVESTING ACTIVITIES
Construction expenditures	(880,785		)	(755,158		)		(1,322,633		)	(1,177,121		)
Allowance for equity funds used during construction	36,869			21,099				57,292			34,492
Nuclear fuel purchases	(14,740		)	(156,246		)		(32,362		)	(159,637		)
Proceeds from the sale of nuclear fuel	36,301			28,884				54,088			28,884
Receipts from storm reserve escrow account	—			8,836				—			8,836
Payments to storm reserve escrow account	(1,984		)	(802		)		(3,297		)	(1,422		)
Changes to securitization account	(1,423		)	79				(8,056		)	(6,538		)
Proceeds from nuclear decommissioning trust fund sales	169,407			125,600				943,306			176,056
Investment in nuclear decommissioning trust funds	(189,721		)	(144,768		)		(973,218		)	(204,500		)
Changes in money pool receivable - net	4,394			(33,039		)		(2,444		)	(50,396		)
Insurance proceeds	3,480			5,305				3,480			5,305
Changes in other investments - net								—			(33,324		)
Net cash flow used in investing activities	(838,202		)	(900,210		)		(1,283,844		)	(1,379,365		)

FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	1,088,941			532,219				1,950,482			646,850
Retirement of long-term debt	(744,222		)	(101,789		)		(1,338,227		)	(296,359		)
Changes in short-term borrowings - net	(43,540		)	30,696				(43,540		)	36,762
Distributions paid:
Common equity	(56,000		)	(91,250		)		(56,000		)	(91,250		)
Other	2,952			(1,988		)		5,507			(2,141		)
Net cash flow provided by financing activities	248,131			367,888				518,222			293,862

Net increase (decrease) in cash and cash equivalents	(6,879		)	1,433				177,678			(158,327		)
Cash and cash equivalents at beginning of period	35,907			213,850				35,907			213,850
Cash and cash equivalents at end of period		$29,028			$215,283				$213,585			$55,523

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized		$138,625			$134,513				$208,028			$189,896
Income taxes		($2,973	)		($116,937	)			($2,973	)		($116,937	)

See Notes to Financial Statements.

															ENTERGY LOUISIANA, LLC AND SUBSIDIARIES	CONSOLIDATED BALANCE SHEETS	ASSETS
June 30, 2018 and December 31, 2017
September 30, 2018 and December 31, 2017								September 30, 2018 and December 31, 2017
(Unaudited)
		2018			2017				2018			2017
		(In Thousands)							(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash			$195			$5,836				$363			$5,836
Temporary cash investments		28,833			30,071				213,222			30,071
Total cash and cash equivalents		29,028			35,907				213,585			35,907
Accounts receivable:
Customer		239,031			254,308				296,121			254,308
Allowance for doubtful accounts		(9,341		)	(8,430		)		(9,634		)	(8,430		)
Associated companies		154,965			143,524				137,252			143,524
Other		61,832			60,893				65,677			60,893
Accrued unbilled revenues		176,347			153,118				177,722			153,118
Total accounts receivable		622,834			603,413				667,138			603,413
Fuel inventory		42,309			39,728				33,608			39,728
Materials and supplies - at average cost		315,966			299,881				326,192			299,881
Deferred nuclear refueling outage costs		40,229			65,711				29,313			65,711
Prepaid taxes		37,919			—				4,736			—
Prepayments and other		54,143			34,035				47,105			34,035
TOTAL		1,142,428			1,078,675				1,321,677			1,078,675

OTHER PROPERTY AND INVESTMENTS
Investment in affiliate preferred membership interests		1,390,587			1,390,587				1,390,587			1,390,587
Decommissioning trust funds		1,334,879			1,312,073				1,395,216			1,312,073
Storm reserve escrow account		286,743			284,759				288,056			284,759
Non-utility property - at cost (less accumulated depreciation)	��	277,814			245,255				285,099			245,255
Other		14,620			18,999				14,773			18,999
TOTAL		3,304,643			3,251,673				3,373,731			3,251,673

UTILITY PLANT
Electric		19,976,144			19,678,536				20,204,568			19,678,536
Natural gas		203,802			191,899				208,480			191,899
Construction work in progress		1,593,553			1,281,452				1,737,898			1,281,452
Nuclear fuel		261,429			337,402				219,139			337,402
TOTAL UTILITY PLANT		22,034,928			21,489,289				22,370,085			21,489,289
Less - accumulated depreciation and amortization		8,686,593			8,703,047				8,787,797			8,703,047
UTILITY PLANT - NET		13,348,335			12,786,242				13,582,288			12,786,242

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $61,519 as of June 30, 2018 and $71,367 as of December 31, 2017)		1,103,639			1,145,842
Other regulatory assets (includes securitization property of $54,910 as of September 30, 2018 and $71,367 as of December 31, 2017)									1,096,597			1,145,842
Deferred fuel costs		168,122			168,122				168,122			168,122
Other		26,786			18,310				27,124			18,310
TOTAL		1,298,547			1,332,274				1,291,843			1,332,274

TOTAL ASSETS			$19,093,953			$18,448,864				$19,569,539			$18,448,864

See Notes to Financial Statements.

														ENTERGY LOUISIANA, LLC AND SUBSIDIARIES	CONSOLIDATED BALANCE SHEETS	LIABILITIES AND EQUITY
June 30, 2018 and December 31, 2017
September 30, 2018 and December 31, 2017							September 30, 2018 and December 31, 2017
(Unaudited)
	2018			2017				2018			2017
	(In Thousands)							(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt		$390,202			$675,002				$3			$675,002
Short-term borrowings	—			43,540				—			43,540
Accounts payable:
Associated companies	92,792			126,685				83,469			126,685
Other	408,990			404,374				337,473			404,374
Customer deposits	152,748			150,623				155,263			150,623
Taxes accrued	—			18,157				—			18,157
Interest accrued	76,318			75,528				77,910			75,528
Deferred fuel costs	2,706			71,447				45,666			71,447
Current portion of unprotected excess accumulated deferred income taxes	199,167			—				157,173			—
Other	75,787			79,037				60,072			79,037
TOTAL	1,398,710			1,644,393				917,029			1,644,393

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	2,180,827			2,050,371				2,244,767			2,050,371
Accumulated deferred investment tax credits	119,435			121,870				118,217			121,870
Regulatory liability for income taxes - net	494,214			725,368				470,300			725,368
Other regulatory liabilities	784,235			761,059				829,011			761,059
Decommissioning	1,256,711			1,140,461				1,272,795			1,140,461
Accumulated provisions	308,251			302,448				310,248			302,448
Pension and other postretirement liabilities	715,027			748,384				688,498			748,384
Long-term debt (includes securitization bonds of $67,568 as of June 30, 2018 and $77,736 as of December 31, 2017)	6,101,521			5,469,069
Long-term debt (includes securitization bonds of $67,634 as of September 30, 2018 and $77,736 as of December 31, 2017)								6,761,120			5,469,069
Other	191,042			176,637				195,776			176,637
TOTAL	12,151,263			11,495,667				12,890,732			11,495,667

Commitments and Contingencies

EQUITY
Member's equity	5,601,431			5,355,204				5,819,729			5,355,204
Accumulated other comprehensive loss	(57,451		)	(46,400		)		(57,951		)	(46,400		)
TOTAL	5,543,980			5,308,804				5,761,778			5,308,804

TOTAL LIABILITIES AND EQUITY		$19,093,953			$18,448,864				$19,569,539			$18,448,864

See Notes to Financial Statements.

																			ENTERGY LOUISIANA, LLC AND SUBSIDIARIES	CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Six Months Ended June 30, 2018 and 2017
For the Nine Months Ended September 30, 2018 and 2017										For the Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Common Equity									Common Equity
	Member’s Equity			Accumulated Other Comprehensive Loss			Total			Member’s Equity			Accumulated Other Comprehensive Loss			Total
	(In Thousands)									(In Thousands)

Balance at December 31, 2016		$5,130,251			($48,442	)		$5,081,809			$5,130,251			($48,442	)		$5,081,809

Net income	218,857			—			218,857			405,141			—			405,141
Other comprehensive loss	—			(680		)	(680		)	—			(1,050		)	(1,050		)
Distributions declared on common equity	(91,250		)	—			(91,250		)	(91,250		)	—			(91,250		)
Other	(27		)	—			(27		)	(62		)	—			(62		)

Balance at June 30, 2017		$5,257,831			($49,122	)		$5,208,709
Balance at September 30, 2017											$5,444,080			($49,492	)		$5,394,588


Balance at December 31, 2017		$5,355,204			($46,400	)		$5,308,804			$5,355,204			($46,400	)		$5,308,804

Net income	295,952			—			295,952			514,260			—			514,260
Other comprehensive loss	—			(1,002		)	(1,002		)	—			(1,502		)	(1,502		)
Distributions declared on common equity	(56,000		)	—			(56,000		)	(56,000		)	—			(56,000		)
Reclassification pursuant to ASU 2018-02	6,262			(10,049		)	(3,787		)	6,262			(10,049		)	(3,787		)
Other	13			—			13			3			—			3

Balance at June 30, 2018		$5,601,431			($57,451	)		$5,543,980
Balance at September 30, 2018											$5,819,729			($57,951	)		$5,761,778

See Notes to Financial Statements.

																				ENTERGY LOUISIANA, LLC AND SUBSIDIARIES	SELECTED OPERATING RESULTS
For the Three and Six Months Ended June 30, 2018 and 2017
For the Three and Nine Months Ended September 30, 2018 and 2017										For the Three and Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Three Months Ended				Increase/						Three Months Ended				Increase/
Description	2018		2017		(Decrease)			%			2018		2017		(Decrease)			%
	(Dollars In Millions)										(Dollars In Millions)
Electric Operating Revenues:
Residential		$268		$279		($11	)	(4	)			$409		$411		($2	)	—
Commercial	222		236		(14		)	(6	)		273		285		(12		)	(4	)
Industrial	369		394		(25		)	(6	)		394		428		(34		)	(8	)
Governmental	17		17		—			—			17		19		(2		)	(11	)
Total billed retail	876		926		(50		)	(5	)		1,093		1,143		(50		)	(4	)
Sales for resale:
Associated companies	97		73		24			33			58		69		(11		)	(16	)
Non-associated companies	15		16		(1		)	(6	)		14		23		(9		)	(39	)
Other	74		57		17			30			31		45		(14		)	(31	)
Total		$1,062		$1,072		($10	)	(1	)			$1,196		$1,280		($84	)	(7	)

Billed Electric Energy Sales (GWh):
Residential	3,104		3,001		103			3			4,658		4,301		357			8
Commercial	2,738		2,729		9			—			3,382		3,228		154			5
Industrial	7,492		7,684		(192		)	(2	)		7,619		7,627		(8		)	—
Governmental	196		194		2			1			216		208		8			4
Total retail	13,530		13,608		(78		)	(1	)		15,875		15,364		511			3
Sales for resale:
Associated companies	1,540		1,241		299			24			1,545		1,164		381			33
Non-associated companies	355		369		(14		)	(4	)		369		616		(247		)	(40	)
Total	15,425		15,218		207			1			17,789		17,144		645			4


	Six Months Ended				Increase/						Nine Months Ended				Increase/
Description	2018		2017		(Decrease)			%			2018		2017		(Decrease)			%
	(Dollars In Millions)										(Dollars In Millions)
Electric Operating Revenues:
Residential		$563		$500		$63		13				$972		$911		$61		7
Commercial	447		431		16			4			720		716		4			1
Industrial	721		719		2			—			1,115		1,147		(32		)	(3	)
Governmental	34		32		2			6			51		51		—			—
Total billed retail	1,765		1,682		83			5			2,858		2,825		33			1
Sales for resale:
Associated companies	171		135		36			27			229		204		25			12
Non-associated companies	30		30		—			—			44		53		(9		)	(17	)
Other	101		89		12			13			132		135		(3		)	(2	)
Total		$2,067		$1,936		$131		7				$3,263		$3,217		$46		1

Billed Electric Energy Sales (GWh):
Residential	6,563		5,853		710			12			11,221		10,154		1,067			11
Commercial	5,399		5,269		130			2			8,781		8,497		284			3
Industrial	14,541		14,645		(104		)	(1	)		22,160		22,272		(112		)	(1	)
Governmental	397		387		10			3			613		595		18			3
Total retail	26,900		26,154		746			3			42,775		41,518		1,257			3
Sales for resale:
Associated companies	2,554		2,235		319			14			4,099		3,399		700			21
Non-associated companies	868		664		204			31			1,237		1,280		(43		)	(3	)
Total	30,322		29,053		1,269			4			48,111		46,197		1,914			4

ENTERGY MISSISSIPPI, INC.

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter 2017

Net income increased ~~$9.9~~$4.2 million primarily due to ~~higher net revenue and~~ a lower effective income tax rate, ~~each after excluding the effect of the stipulation related to the effects of the Tax Act, discussed below. The increase is~~ partially offset by higher other operation and maintenance ~~expenses and higher depreciation and amortization~~ expenses.

~~Six~~Nine Months Ended ~~June~~September 30, 2018 Compared to ~~Six~~Nine Months Ended ~~June~~September 30, 2017

Net income increased ~~$15.6~~$19.8 million primarily due to ~~higher net revenue and~~ a lower effective income tax rate and higher net revenue, each after excluding the effect of the ~~stipulation related~~return of unprotected excess accumulated deferred income taxes to ~~the effects of the Tax Act,~~customers, discussed below. The increase is partially offset by higher other operation and maintenance expenses and higher depreciation and amortization expenses.

Net Revenue

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter 2017

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges (credits). Following is an analysis of the change in net revenue comparing the ~~second~~third quarter 2018 to the ~~second~~third quarter 2017:



	Amount
	(In Millions)
2017 net revenue		$~~174.2~~201.3
~~Regulatory charge resulting from stipulation related~~Return of unprotected excess accumulated deferred income taxes to ~~the effects of the Tax Act~~customers	(~~127.2~~25.8		)
~~Retail electric price~~	~~4.2~~
Volume/weather	~~11.2~~3.5
Other	~~0.5~~(0.1		)
2018 net revenue		$~~62.9~~178.9

The ~~regulatory charge resulting from stipulation related~~return of unprotected excess accumulated deferred income taxes to ~~the effects of the Tax Act~~customers is due to the return of unprotected excess accumulated deferred income taxes ~~in June~~through customer bill credits over a three-month period from July 2018 through September 2018 per an agreement approved by the MPSC in June 2018 ~~that resulted in a reduction in net utility plant~~resulting from the stipulation related to the effects of ~~$127.2 million.~~the Tax Cuts and Jobs Act. There is no effect on net income as the ~~regulatory charge~~reduction in net revenue is offset by a reduction in income tax expense. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity regarding the Tax ~~Act.~~

The retail electric price variance is primarily due to higher storm damage rider revenues. Entergy Mississippi resumed billing the storm damage rider effective with the September 2017 billing cycle. See Note 2 to the financial statements hereinCuts and ~~in the Form 10-K for further discussion of the storm damage rider.~~Jobs Act.

The volume/weather variance is primarily due to an increase of 79257 GWh, or 3%7%, in billed electricity usage, including the effect of more favorable weather on residential sales.

~~130~~138

Table of Contents

Entergy Mississippi, Inc.

Management's Financial Discussion and Analysis

~~Six~~Nine Months Ended ~~June~~September 30, 2018 Compared to ~~Six~~Nine Months Ended ~~June~~September 30, 2017

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges (credits). Following is an analysis of the change in net revenue comparing the ~~six~~nine months ended ~~June~~September 30, 2018 to the ~~six~~nine months ended ~~June~~September 30, 2017:



	Amount
	(In Millions)
2017 net revenue		$~~328.3~~529.6
~~Regulatory charge resulting from stipulation related~~Return of unprotected excess accumulated deferred income taxes to ~~the effects of the Tax Act~~customers	(~~127.2~~153.0		)
Retail electric price	~~9.3~~8.6
Volume/weather	~~16.0~~19.5
Other	~~1.0~~1.6
2018 net revenue		$~~227.4~~406.3

The ~~regulatory charge resulting from stipulation related~~return of unprotected excess accumulated deferred income taxes to ~~the effects of the Tax Act~~customers is due to a regulatory charge recorded in June 2018 that resulted in a $127.2 million reduction in net utility plant and the return of unprotected excess accumulated deferred income taxes ~~in June~~through customer bill credits over a three-month period from July 2018 through September 2018, each per an agreement approved by the MPSC in June 2018, ~~that resulted in a reduction in net utility plant~~resulting from the stipulation related to the effects of ~~$127.2 million.~~the Tax Cuts and Jobs Act. There is no effect on net income as the ~~regulatory charge is~~reductions in net revenue are offset by a reduction in income tax expense. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

The retail electric price variance is primarily due to higher storm damage rider revenues. Entergy Mississippi resumed billing the storm damage rider effective with the September 2017 billing cycle and ceased billing the storm damage rider effective with the August 2018 billing cycle. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the storm damage rider.

The volume/weather variance is primarily due to an increase of ~~388~~645 GWh, or 7%, in billed electricity usage, including the effect of more favorable weather on residential sales.

Other Income Statement Variances

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter 2017

Other operation and maintenance expenses increased primarily due to:

a $5.8 million loss on the sale of fuel oil inventory per an agreement approved by the MPSC in June 2018 resulting from the stipulation related to the effects of the Tax Act. There is no effect on net income as the loss on the sale of fuel oil inventory is offset by a reduction in income tax expense;

an increase of ~~$4.7~~$3.2 million in ~~storm damage provisions and an increase of $2 million in vegetation maintenance costs. The increase was partially offset by a decrease of $2.1 million in~~ fossil-fueled generation expenses primarily due to ~~lower~~higher long-term service agreement ~~costs.~~costs; and

an increase of $1.6 million in customer service costs primarily due to higher contract costs and write-offs of customer accounts.

Taxes other than income taxes increased primarily due to an increase in ad valorem taxes and an increase in local franchise taxes. Ad valorem taxes increased primarily due to higher assessments. Local franchise taxes increased primarily due to higher revenues in the third quarter 2018 as compared to the third quarter 2017.

139

Table of Contents

Entergy Mississippi, Inc.

Management's Financial Discussion and Analysis

Nine Months Ended September 30, 2018 Compared to Nine Months Ended September 30, 2017

Other operation and maintenance expenses increased primarily due to:

an increase of $10.2 million in storm damage provisions. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of storm cost ~~recovery.~~recovery;

an increase of $2.6 million in vegetation maintenance costs; and

an increase of $2.5 million in customer service costs primarily due to higher contract costs and write-offs of customer accounts.

~~Depreciation and amortization expenses~~Taxes other than income taxes increased primarily due to ~~additions to plant~~an increase in ~~service.~~

~~Six Months Ended June 30, 2018 Compared to Six Months Ended June 30, 2017~~

~~Other operation~~ad valorem taxes and ~~maintenance expenses~~an increase in local franchise taxes. Ad valorem taxes increased primarily due to an increase of $9.9 million in storm damage provisions and an increase of $1.4 million in vegetation maintenance costs. The increase was partially offset by a decrease of $2.1 million in fossil-fueled generation expenseshigher assessments. Local franchise taxes increased primarily due to ~~lower long-term service agreement costs, partially offset by an overall~~ higher ~~scope of work including plant outages. See Note 2~~revenues in 2018 as compared to the ~~financial statements herein and~~same period in ~~the Form 10-K for a discussion of storm cost recovery.~~2017.

Depreciation and amortization expenses increased primarily due to additions to plant in service.

Interest expense increased primarily due to the issuance of $150 million of 3.25% Series first mortgage bonds in November 2017.

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Income Taxes

The effective income tax rate was ~~150.1%~~(46.7%) for the ~~second~~third quarter ~~2018 and 231.4% for the six months ended June 30,~~ 2018. The ~~differences~~difference in the effective income tax ~~rates~~rate for the ~~second~~third quarter ~~2018 and the six months ended June 30,~~ 2018 versus the federal statutory rate of 21% ~~were~~was primarily due to the amortization of excess accumulated deferred ~~income taxes and state~~ income taxes. See Notes 2 and 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was ~~37.6%~~1,039.9% for the ~~second quarter 2017.~~nine months ended September 30, 2018. The difference in the effective income tax rate for the ~~second~~nine months ended September 30, 2018 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, state income taxes, and book and tax differences related to the allowance for equity funds used during construction. See Notes 2 and 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rates were 37.8% for the third quarter 2017 and 38.4% for the nine months ended September 30, 2017. The differences in the effective income tax rates for the third quarter 2017 and the nine months ended September 30, 2017 versus the federal statutory rate of 35% ~~was~~were primarily due to state income taxes, partially offset by book and tax differences related to the allowance for equity funds used during construction.

The effective income tax rate was 39.0% for the six months ended June 30, 2017. The difference in the effective income tax rate for the six months ended June 30, 2017 versus the federal statutory rate of 35% was primarily due to state income taxes and a write-off of a stock-based compensation deferred tax asset, partially offset by book and tax differences related to the allowance for equity funds used during construction.

Income Tax Legislation

See the “Income Tax Legislation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for a discussion of the Tax Cuts and Jobs Act, the federal income tax legislation enacted in December 2017. Note 3 to the financial statements in the Form 10-K contains additional discussion of the effect of the Tax Act on 2017 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act.Note 10 to the financial statements herein contains updates to that discussion. Note 2 to the financial statements herein and in the Form 10-K contains a discussion of proceedings commenced or other responses by Entergy and Entergy’s regulators to the Tax Act.

~~Liquidity and Capital Resources~~

~~Cash Flow~~

~~Cash flows for the six months ended June 30, 2018 and 2017 were as follows:~~

2018 2017
(In Thousands)
Cash and cash equivalents at beginning of period
$6,096

$76,834

Cash flow provided by (used in):
Operating activities 106,818
53,839
Investing activities (182,349 ) (185,687 )
Financing activities 69,453
55,736
Net decrease in cash and cash equivalents (6,078 ) (76,112 )

Cash and cash equivalents at end of period
$18

$722

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Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2018 and 2017 were as follows:



	2018			2017
	(In Thousands)
Cash and cash equivalents at beginning of period		$6,096			$76,834

Cash flow provided by (used in):
Operating activities	218,024			129,314
Investing activities	(268,165		)	(300,966		)
Financing activities	44,090			94,867
Net decrease in cash and cash equivalents	(6,051		)	(76,785		)

Cash and cash equivalents at end of period		$45			$49

Operating Activities

Net cash flow provided by operating activities increased ~~$53~~$88.7 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to:

the timing of ~~payments to vendors;~~

~~the timing of~~ recovery of fuel and purchased power costs; ~~and~~

$26.2 million in proceeds from the sale of fuel oil inventory in 2018;

the effect of favorable weather on billed sales;

the timing of collection of storm damage rider revenues. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the storm damage ~~rider.~~rider; and

a decrease of $7.9 million in storm spending in 2018.

The increase was partially offset by by:

the return of unprotected excess accumulated deferred income taxes to customers;

income tax refunds of $15.1 million in 2017. Entergy Mississippi received state income tax refunds of $15.1 million in 2017 in accordance with an intercompany income tax allocation agreement resulting from the carryback of net operating ~~losses.~~losses; and

an increase of $6.2 million in interest paid in 2018 resulting from an increase in interest expense.

Investing Activities

Net cash flow used in investing activities decreased ~~$3.3~~$32.8 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to a decrease of $48.8 million in transmission construction expenditures primarily due to a lower scope of work performed in 2018 as compared to the same period in 2017 and a decrease of $13.3 million in storm spending in 2018. The decrease was partially offset by:

money pool activity;

an increase of $7.5 million in information technology construction expenditures primarily due to increased spending on various technology projects; and

an increase of $7.3 million related to facility site improvements.

Decreases in Entergy Mississippi’s receivable from the money pool are a source of cash flow, and Entergy Mississippi’s receivable from the money pool decreased by $1.6 million for the nine months ended September 30,

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2018 compared to decreasing by $10.6 million for the nine months ended September 30, 2017. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Net cash flow provided by financing activities ~~increased $13.7~~decreased $50.8 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to money pool ~~activity~~activity. The decrease was partially offset by a decrease of $10.5 million in common stock dividends paid in 2018 resulting from Entergy Mississippi’s routine evaluation of its ability to pay dividends based on historical and planned capital investments and an increase in advances received from customers for transmission projects.

Increases in Entergy Mississippi’s payable to the money pool are a source of cash flow, and Entergy Mississippi’s payable to the money pool increased by ~~$63.4~~$33.8 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to increasing by ~~$56.3~~$106.2 million for the ~~six~~nine months ended ~~June~~September 30, 2017.

Capital Structure

Entergy Mississippi’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio for Entergy Mississippi is primarily due to an increase in retained earnings.


	June 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Debt to capital	50.2	%	51.5	%	49.3	%	51.5	%
Effect of subtracting cash	—	%	(0.2	%)	—	%	(0.2	%)
Net debt to net capital	50.2	%	51.3	%	49.3	%	51.3	%

Net debt consists of debt less cash and cash equivalents. Debt consists of short-term borrowings and long-term debt, including the currently maturing portion. Capital consists of debt, preferred stock without sinking fund, and common equity. Net capital consists of capital less cash and cash equivalents. Entergy Mississippi uses the debt to capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Mississippi’s financial condition. Entergy Mississippi uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Mississippi’s financial condition because net debt indicates Entergy Mississippi’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

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Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Mississippi’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

Entergy Mississippi is developing its capital investment plan for 2019 through 2021 and currently anticipates making $1.7 billion in capital investments during that period. The preliminary estimate includes amounts associated with specific investments such as the Choctaw Generating Station, discussed below; transmission projects to enhance reliability, reduce congestion, and enable economic growth; distribution spending to enhance reliability and improve service to customers, including advanced meters and related investments; resource planning, including potential generation projects; system improvements; software and security; and other investments. Estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints and requirements, environmental compliance, business opportunities, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital.

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Entergy Mississippi’s receivables from or (payables to) the money pool were as follows:

June 30,
2018
December 31, 2017
June 30,
2017
December 31, 2016
(In Thousands)
($63,394) $1,633 ($56,299) $10,595

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

In May 2018, Entergy Mississippi renewed three of its four separate credit facilities through May 2019, decreasing the aggregate amount available for borrowing under the credit facilities to $82.5 million. No borrowings were outstanding under the credit facilities as of ~~June~~September 30, 2018. In addition, Entergy Mississippi is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of ~~June~~September 30, 2018, ~~$20.2~~$11.2 million letters of credit were outstanding under Entergy Mississippi’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

Choctaw Generating Station

In August 2018, Entergy Mississippi announced that it signed an asset purchase agreement to acquire from a subsidiary of GenOn Energy Inc. the Choctaw Generating Station, an 810 MW natural gas fired combined-cycle turbine plant located near French Camp, Mississippi. The purchase price is expected to be approximately $314 million. Entergy Mississippi also expects to invest in various plant upgrades at the facility after closing and expects the total cost of the acquisition to be approximately $401 million. The purchase is contingent upon, among other things, obtaining necessary approvals, including full cost recovery, from applicable federal and state regulatory and permitting agencies. These include regulatory approvals from the MPSC and the FERC, as well as clearance under the Hart-Scott-Rodino Antitrust Improvements Act. In October 2018, Entergy Mississippi filed an application with the MPSC seeking approval of the acquisition and cost recovery. In a separate filing in October 2018, Entergy Mississippi proposed revisions to its formula rate plan that would provide for a mechanism, the interim capacity rate adjustment mechanism, in the formula rate plan to recover the non-fuel related costs of additional owned capacity acquired by Entergy Mississippi, including the non-fuel annual ownership costs of the Choctaw Generating Station, as well as to allow similar cost recovery treatment for other future capacity additions approved by the MPSC. Closing is expected to occur by the end of 2019.

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - State and Local Rate Regulation and Fuel-Cost Recovery” in the Form 10-K for a discussion of the formula rate plan and fuel and purchased power cost recovery. The following are updates to that discussion.

Mississippi Attorney General Complaint

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companies’ motion to strike the Attorney General’s jury demand. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019.

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. In June 2018, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a stipulation that confirmed that Entergy Mississippi’s earned returns for both the 2017 look-back filing and 2018 test year were within the respective formula rate plan bandwidths. In June 2018 the MPSC approved the stipulation, which resulted in no change in rates.See Note 2 to the financial statements herein and in the Form 10-K for ~~additional~~further discussion regarding the proposed treatment of the effects of the lower federal corporate income tax rate.

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Entergy Mississippi’s formula rate plan includes a look-back evaluation report filing in March 2019 that will compare actual 2018 results to the performance-adjusted allowed return on rate base. To the extent that Entergy Mississippi ~~Inc.~~expects this look-back evaluation report to show the 2018 earned return on rate base exceeded the formula rate plan performance-adjusted bandwidth, Entergy Mississippi will record a regulatory provision in the fourth quarter 2018.

~~Management's Financial Discussion and Analysis~~

Internal Restructuring

It is currently contemplated that Entergy Mississippi would undertake a multi-step restructuring, which would include the following:

Entergy Mississippi would convert from a Mississippi corporation to a Texas corporation.

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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.

Advanced Metering Infrastructure (AMI) Filings

Storm Cost Recovery Filings with Retail Regulators

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Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation.

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for a discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Mississippi’s accounting for utility regulatory accounting, unbilled revenue, impairment of long-lived assets and trust fund investments, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

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New Accounting Pronouncements

See “New Accounting Pronouncements” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for further discussion of new accounting pronouncements.

																										ENTERGY MISSISSIPPI, INC.	INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2018 and 2017
For the Three and Nine Months Ended September 30, 2018 and 2017													For the Three and Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Three Months Ended						Six Months Ended							Three Months Ended						Nine Months Ended
	2018			2017			2018			2017				2018			2017			2018			2017
	(In Thousands)						(In Thousands)							(In Thousands)						(In Thousands)
OPERATING REVENUES
Electric		$353,689			$291,212			$669,432			$549,655				$367,734			$349,197			$1,037,166			$898,852

OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	65,663			46,048			129,191			85,188				78,533			61,681			207,724			146,869
Purchased power	97,154			75,253			184,610			146,323				104,787			90,086			289,397			236,409
Other operation and maintenance	64,585			59,002			124,043			113,624				69,936			56,713			193,979			170,337
Taxes other than income taxes	23,794			23,978			49,188			47,950				26,024			23,568			75,212			71,518
Depreciation and amortization	38,359			35,442			76,541			70,759				37,752			36,176			114,293			106,935
Other regulatory charges (credits) - net	127,935			(4,306		)	128,228			(10,143		)		5,487			(3,840		)	133,715			(13,983		)
TOTAL	417,490			235,417			691,801			453,701				322,519			264,384			1,014,320			718,085

OPERATING INCOME (LOSS)	(63,801		)	55,795			(22,369		)	95,954
OPERATING INCOME														45,215			84,813			22,846			180,767

OTHER INCOME
Allowance for equity funds used during construction	2,122			2,332			4,100			4,175				2,251			2,566			6,351			6,741
Interest and investment income	—			7			25			33				1			—			26			33
Miscellaneous - net	(1,411		)	(1,086		)	(1,982		)	(2,062		)		116			(832		)	(1,866		)	(2,894		)
TOTAL	711			1,253			2,143			2,146				2,368			1,734			4,511			3,880

INTEREST EXPENSE
Interest expense	14,061			12,568			27,966			25,240				13,950			12,713			41,916			37,953
Allowance for borrowed funds used during construction	(890		)	(913		)	(1,718		)	(1,633		)		(944		)	(1,048		)	(2,662		)	(2,681		)
TOTAL	13,171			11,655			26,248			23,607				13,006			11,665			39,254			35,272

INCOME (LOSS) BEFORE INCOME TAXES	(76,261		)	45,393			(46,474		)	74,493				34,577			74,882			(11,897		)	149,375

Income taxes	(114,503		)	17,090			(107,559		)	29,032				(16,156		)	28,337			(123,715		)	57,369

NET INCOME	38,242			28,303			61,085			45,461				50,733			46,545			111,818			92,006

Preferred dividend requirements and other	239			239			477			477				238			238			715			715

EARNINGS APPLICABLE TO COMMON STOCK		$38,003			$28,064			$60,608			$44,984				$50,495			$46,307			$111,103			$91,291

See Notes to Financial Statements.

(Page left blank intentionally)

														ENTERGY MISSISSIPPI, INC.	STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2018 and 2017
For the Nine Months Ended September 30, 2018 and 2017							For the Nine Months Ended September 30, 2018 and 2017
(Unaudited)
	2018			2017				2018			2017
	(In Thousands)							(In Thousands)
OPERATING ACTIVITIES
Net income		$61,085			$45,461				$111,818			$92,006
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization	76,541			70,759				114,293			106,935
Deferred income taxes, investment tax credits, and non-current taxes accrued	29,577			31,740				40,537			65,204
Changes in assets and liabilities:
Receivables	(32,365		)	(7,952		)		(49,456		)	(31,085		)
Fuel inventory	(977		)	6,312				33,705			8,059
Accounts payable	29,476			(1,398		)		(9,845		)	(2,644		)
Taxes accrued	(45,736		)	(21,361		)		(24,280		)	(5,815		)
Interest accrued	(3,792		)	40				(4,767		)	(2,366		)
Deferred fuel costs	6,532			(13,622		)		9,826			(27,344		)
Other working capital accounts	(9,698		)	(1,473		)		(8,348		)	(279		)
Provisions for estimated losses	7,242			(6,699		)		7,894			(10,274		)
Other regulatory assets	(666		)	(26,958		)		26,060			(33,323		)
Other regulatory liabilities	(127,047		)	(4,237		)		(139,063		)	(5,118		)
Pension and other postretirement liabilities	(9,336		)	(10,692		)		(15,987		)	(18,863		)
Other assets and liabilities	125,982			(6,081		)		125,637			(5,779		)
Net cash flow provided by operating activities	106,818			53,839				218,024			129,314

INVESTING ACTIVITIES
Construction expenditures	(187,219		)	(199,873		)		(275,189		)	(313,910		)
Allowance for equity funds used during construction	4,100			4,175				6,351			6,741
Changes in money pool receivable - net	1,633			10,595				1,633			10,595
Change in other investments								—			(3,185		)
Other	(863		)	(584		)		(960		)	(1,207		)
Net cash flow used in investing activities	(182,349		)	(185,687		)		(268,165		)	(300,966		)

FINANCING ACTIVITIES
Changes in money pool payable - net	63,394			56,299				33,816			106,180
Dividends paid:
Common stock								—			(10,500		)
Preferred stock	(477		)	(477		)		(715		)	(715		)
Other	6,536			(86		)		10,989			(98		)
Net cash flow provided by financing activities	69,453			55,736				44,090			94,867

Net decrease in cash and cash equivalents	(6,078		)	(76,112		)		(6,051		)	(76,785		)
Cash and cash equivalents at beginning of period	6,096			76,834				6,096			76,834
Cash and cash equivalents at end of period		$18			$722				$45			$49

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized		$30,490			$24,021				$44,781			$38,549
Income taxes		$—			($15,087	)			$—			($15,087	)

See Notes to Financial Statements.

														ENTERGY MISSISSIPPI, INC.	BALANCE SHEETS	ASSETS
June 30, 2018 and December 31, 2017
September 30, 2018 and December 31, 2017							September 30, 2018 and December 31, 2017
(Unaudited)
	2018			2017				2018			2017
	(In Thousands)							(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash		$11			$1,607				$38			$1,607
Temporary cash investments	7			4,489				7			4,489
Total cash and cash equivalents	18			6,096				45			6,096
Accounts receivable:
Customer	93,751			72,039				102,986			72,039
Allowance for doubtful accounts	(648		)	(574		)		(830		)	(574		)
Associated companies	46,456			45,081				54,578			45,081
Other	9,747			9,738				16,294			9,738
Accrued unbilled revenues	61,966			54,256				55,335			54,256
Total accounts receivable	211,272			180,540				228,363			180,540
Deferred fuel costs	25,912			32,444				22,618			32,444
Fuel inventory - at average cost	46,583			45,606				11,901			45,606
Materials and supplies - at average cost	44,675			42,571				46,041			42,571
Prepayments and other	12,034			7,041				10,674			7,041
TOTAL	340,494			314,298				319,642			314,298

OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,584			4,592				4,580			4,592
Storm reserve escrow account	32,187			31,969				32,284			31,969
TOTAL	36,771			36,561				36,864			36,561

UTILITY PLANT
Electric	4,557,995			4,660,297				4,624,415			4,660,297
Property under capital lease	—			125				—			125
Construction work in progress	175,039			149,367				181,766			149,367
TOTAL UTILITY PLANT	4,733,034			4,809,789				4,806,181			4,809,789
Less - accumulated depreciation and amortization	1,624,479			1,681,306				1,652,552			1,681,306
UTILITY PLANT - NET	3,108,555			3,128,483				3,153,629			3,128,483

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets	398,575			397,909				371,849			397,909
Other	3,398			2,124				4,859			2,124
TOTAL	401,973			400,033				376,708			400,033

TOTAL ASSETS		$3,887,793			$3,879,375				$3,886,843			$3,879,375

See Notes to Financial Statements.

										ENTERGY MISSISSIPPI, INC.	BALANCE SHEETS	LIABILITIES AND EQUITY
June 30, 2018 and December 31, 2017
September 30, 2018 and December 31, 2017					September 30, 2018 and December 31, 2017
(Unaudited)
	2018		2017			2018		2017
	(In Thousands)					(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt							$150,000		$—
Accounts payable:
Associated companies		$112,877		$55,689		67,933		55,689
Other	111,101		77,326			80,909		77,326
Customer deposits	83,348		83,654			84,260		83,654
Taxes accrued	37,107		82,843			58,563		82,843
Interest accrued	19,109		22,901			18,134		22,901
Current portion of unprotected excess accumulated deferred income taxes	35,415		—			9,262		—
Other	9,723		12,785			10,169		12,785
TOTAL	408,680		335,198			479,230		335,198

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	520,387		488,806			533,861		488,806
Accumulated deferred investment tax credits	8,787		8,867			8,747		8,867
Regulatory liability for income taxes - net	246,670		411,011			239,118		411,011
Asset retirement cost liabilities	9,840		9,219			9,977		9,219
Accumulated provisions	52,006		44,764			52,658		44,764
Pension and other postretirement liabilities	92,161		101,498			85,509		101,498
Long-term debt	1,270,559		1,270,122			1,120,830		1,270,122
Other	19,844		11,639			47,559		11,639
TOTAL	2,220,254		2,345,926			2,098,259		2,345,926

Commitments and Contingencies

Preferred stock without sinking fund	20,381		20,381			20,381		20,381

COMMON EQUITY
Common stock, no par value, authorized 12,000,000 shares; issued and outstanding 8,666,357 shares in 2018 and 2017	199,326		199,326			199,326		199,326
Capital stock expense and other	167		167			167		167
Retained earnings	1,038,985		978,377			1,089,480		978,377
TOTAL	1,238,478		1,177,870			1,288,973		1,177,870

TOTAL LIABILITIES AND EQUITY		$3,887,793		$3,879,375			$3,886,843		$3,879,375

See Notes to Financial Statements.

																					ENTERGY MISSISSIPPI, INC.	STATEMENTS OF CHANGES IN COMMON EQUITY
For the Six Months Ended June 30, 2018 and 2017
For the Nine Months Ended September 30, 2018 and 2017											For the Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Common Equity										Common Equity
	Common Stock		Capital Stock Expense and Other		Retained Earnings			Total			Common Stock		Capital Stock Expense and Other		Retained Earnings			Total
	(In Thousands)										(In Thousands)

Balance at December 31, 2016		$199,326		$167		$895,298			$1,094,791			$199,326		$167		$895,298			$1,094,791

Net income	—		—		45,461			45,461			—		—		92,006			92,006
Common stock dividends											—		—		(10,500		)	(10,500		)
Preferred stock dividends	—		—		(477		)	(477		)	—		—		(715		)	(715		)

Balance at June 30, 2017		$199,326		$167		$940,282			$1,139,775
Balance at September 30, 2017												$199,326		$167		$976,089			$1,175,582


Balance at December 31, 2017		$199,326		$167		$978,377			$1,177,870			$199,326		$167		$978,377			$1,177,870

Net income	—		—		61,085			61,085			—		—		111,818			111,818
Preferred stock dividends	—		—		(477		)	(477		)	—		—		(715		)	(715		)

Balance at June 30, 2018		$199,326		$167		$1,038,985			$1,238,478
Balance at September 30, 2018												$199,326		$167		$1,089,480			$1,288,973

See Notes to Financial Statements.

																		ENTERGY MISSISSIPPI, INC.	SELECTED OPERATING RESULTS
For the Three and Six Months Ended June 30, 2018 and 2017
For the Three and Nine Months Ended September 30, 2018 and 2017								For the Three and Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Three Months Ended				Increase/				Three Months Ended				Increase/
Description	2018		2017		(Decrease)		%		2018		2017		(Decrease)			%
	(Dollars In Millions)								(Dollars In Millions)
Electric Operating Revenues:
Residential		$133		$111		$22	20			$170		$158		$12		8
Commercial	117		101		16		16		127		121		6			5
Industrial	46		38		8		21		44		41		3			7
Governmental	12		10		2		20		12		11		1			9
Total billed retail	308		260		48		18		353		331		22			7
Sales for resale:
Non-associated companies	12		7		5		71		8		4		4			100
Other	34		24		10		42		7		14		(7		)	(50	)
Total		$354		$291		$63	22			$368		$349		$19		5

Billed Electric Energy Sales (GWh):
Residential	1,199		1,135		64		6		1,899		1,747		152			9
Commercial	1,147		1,142		5		—		1,475		1,407		68			5
Industrial	627		618		9		1		692		665		27			4
Governmental	102		101		1		1		128		118		10			8
Total retail	3,075		2,996		79		3		4,194		3,937		257			7
Sales for resale:
Non-associated companies	407		312		95		30		303		251		52			21
Total	3,482		3,308		174		5		4,497		4,188		309			7


	Six Months Ended				Increase/				Nine Months Ended				Increase/
Description	2018		2017		(Decrease)		%		2018		2017		(Decrease)			%
	(Dollars In Millions)								(Dollars In Millions)
Electric Operating Revenues:
Residential		$281		$222		$59	27			$451		$380		$71		19
Commercial	228		193		35		18		355		314		41			13
Industrial	89		74		15		20		133		115		18			16
Governmental	22		19		3		16		34		30		4			13
Total billed retail	620		508		112		22		973		839		134			16
Sales for resale:
Non-associated companies	13		12		1		8		21		16		5			31
Other	36		30		6		20		43		44		(1		)	(2	)
Total		$669		$550		$119	22			$1,037		$899		$138		15

Billed Electric Energy Sales (GWh):
Residential	2,648		2,325		323		14		4,547		4,072		475			12
Commercial	2,247		2,204		43		2		3,722		3,611		111			3
Industrial	1,224		1,204		20		2		1,916		1,869		47			3
Governmental	201		199		2		1		329		317		12			4
Total retail	6,320		5,932		388		7		10,514		9,869		645			7
Sales for resale:
Non-associated companies	600		493		107		22		903		744		159			21
Total	6,920		6,425		495		8		11,417		10,613		804			8

ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter 2017

Net income increased ~~$3.4~~$2.9 million primarily due to ~~higher net revenue and~~ a lower effective income tax rate and higher net revenue, after excluding the effect of the return of unprotected excess accumulated deferred income taxes to customers which is offset in income taxes, partially offset by higher other operation and maintenance expenses.

~~Six~~Nine Months Ended ~~June~~September 30, 2018 Compared to ~~Six~~Nine Months Ended ~~June~~September 30, 2017

Net income increased ~~$3.3~~$6.2 million primarily due to ~~higher net revenue and~~ a lower effective income tax rate and higher net revenue, partially offset by higher other operation and maintenance ~~expenses, higher taxes other than income taxes, and higher depreciation and amortization~~ expenses.

Net Revenue

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter 2017

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges. Following is an analysis of the change in net revenue comparing the ~~second~~third quarter 2018 to the ~~second~~third quarter 2017:



	Amount
	(In Millions)
2017 net revenue		$~~79.3~~88.3
Return of unprotected excess accumulated deferred income taxes to customers	(9.0		)
Volume/weather	~~4.7~~1.0
Retail electric price	~~(2.2~~2.3		)
Other	~~1.4~~(0.9		)
2018 net revenue		$~~83.2~~81.7

The ~~volume/weather variance~~return of unprotected excess accumulated deferred income taxes to customers resulted from the return of unprotected excess accumulated deferred income taxes through the fuel adjustment clause beginning in July 2018. There is ~~primarily due to an increase of 11 GWh, or 1%,~~no effect on net income as the reduction in ~~billed electricity usage, including the effect of more favorable weather primarily on residential sales and~~net revenue is offset by a ~~1% increase~~reduction in ~~the average number of electric customers.~~

~~The retail electric price variance is primarily due to:~~

~~a decrease in the purchased power and capacity acquisition cost recovery rider primarily due to a decrease in the revenue requirement related to Power Block 1 of the Union Power Station; and~~

~~regulatory charges of $1.6 million recorded in the second quarter 2018 as a result of an agreement with the City Council to return the benefits of the lower federal~~ income tax ~~rate in 2018 to customers.~~

expense. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of ~~the credits associated with Entergy New Orleans’s internal restructuring and~~ regulatory ~~proceedings related to the enactment of~~activity regarding the Tax Cuts and Jobs Act.

The volume/weather variance is primarily due to an increase of 111 GWh, or 7%, in billed electricity usage, including the effect of more favorable weather on residential and commercial sales and a 1% increase in the average number of electric customers.

The retail electric price variance is primarily due to an increase in the purchased power and capacity acquisition cost recovery rider primarily due to higher credits to customers in 2017 as part of the Entergy New Orleans internal restructuring agreement in principle, partially offset by a decrease in the revenue requirement related to Power Block

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1 of the Union Power Station. See Note 2 to the financial statements in the Form 10-K for further discussion of the credits associated with Entergy New Orleans’s internal restructuring.

~~Six~~Nine Months Ended ~~June~~September 30, 2018 Compared to ~~Six~~Nine Months Ended ~~June~~September 30, 2017

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges. Following is an analysis of the change in net revenue comparing the ~~six~~nine months ended ~~June~~September 30, 2018 to ~~six~~nine months ended ~~June~~September 30, 2017:



	Amount
	(In Millions)
2017 net revenue		$~~149.5~~237.8
Volume/weather	~~8.3~~9.3
Net gas revenue	~~3.6~~2.4
Retail electric price	(~~4.8~~2.5		)
Return of unprotected excess accumulated deferred income taxes to customers	(9.0		)
Other	~~1.6~~2.0
2018 net revenue		$~~158.2~~240.0

The volume/weather variance is primarily due to an increase of ~~139~~250 GWh, or 5%6%, in billed electricity usage, including the effect of more favorable weather ~~primarily~~ on residential and commercial sales and a 1% increase in the average number of electric customers.

The net gas revenue variance is primarily due to the effect of more favorable weather on residential and commercial sales.

The retail electric price variance is primarily due ~~to:~~

to regulatory charges of ~~$3.3~~$4.1 million recorded in 2018 as a result of an agreement with the City Council to return the benefits of the lower federal income tax rate in 2018 to ~~customers; and~~

a decrease in the purchased power and capacity acquisition cost recovery rider primarily due to credits to customers as part of the Entergy New Orleans internal restructuring agreement in principle, effective with the first billing cycle of June 2017.

customers. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory proceedings.

The return of unprotected excess accumulated deferred income taxes to customers resulted from the ~~credits associated with Entergy New Orleans’s internal restructuring and regulatory proceedings related~~return of unprotected excess accumulated deferred income taxes through the fuel adjustment clause beginning in July 2018. There is no effect on net income as the reduction in net revenue is offset by a reduction in income tax expense. See Note 2 to the ~~enactment~~financial statements herein and in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

Other Income Statement Variances

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter ~~2017~~

~~Other operation and maintenance expenses increased primarily due to an increase of $1.1 million in loss provisions and several individually insignificant items.~~

~~Six Months Ended June 30, 2018 Compared to Six Months Ended June 30,~~ 2017

Other operation and maintenance expenses increased primarily due to:

an increase of ~~$2.4 million in distribution expenses primarily due to~~ ~~an overall higher scope of work performed in 2018 as compared to the same period in 2017~~;

~~an increase of $1.5~~$1.8 million in energy efficiency costs;

an increase of ~~$1.5~~$0.9 million in ~~loss provisions;~~information technology costs primarily due to higher software maintenance costs and higher contract costs; and

~~several individually insignificant items.~~an increase of $0.8 million in customer service costs primarily due to higher contract costs and write-offs of customer accounts.

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~~Taxes other than income taxes~~Nine Months Ended September 30, 2018 Compared to Nine Months Ended September 30, 2017

Other operation and maintenance expenses increased primarily due to to:

an increase of $3.3 million in ~~local franchise taxes~~energy efficiency costs;

an increase of $3 million in distribution expenses primarily due to higher ~~electric and gas retail revenues in 2018~~contract labor costs, including an increase resulting from the timing of storm hardening work as compared to the ~~same period~~prior year;

an increase of $1.6 million in ~~2017.~~

~~Depreciation and amortization expenses increased~~customer service costs primarily due to ~~additions~~higher contract costs and write-offs of customer accounts;

an increase of $1.2 million in information technology costs primarily due to ~~plant~~higher software maintenance costs and higher contract costs; and

an increase of $1.1 million in ~~service.~~loss provisions.

Income Taxes

The effective income tax ~~rate was 21.1%~~rates were (20.0%) for the ~~second~~third quarter 2018 and 7.2% for the nine months ended September 30, 2018. The ~~difference~~differences in the effective income tax ~~rate~~rates for the ~~second~~third quarter 2018 ~~versus the federal statutory rate of 21% was primarily due to state income taxes~~ and the ~~provision for uncertain tax positions, partially offset by flow-through tax accounting and certain book and tax differences related to utility plant items.~~

~~The effective income tax rate was 20.5% for the six~~nine months ended ~~June 30, 2018. The difference in the effective income tax rate for the six months ended June~~September 30, 2018 versus the federal statutory rate of 21% ~~was~~were primarily due to the amortization of excess accumulated deferred income taxes and flow-through tax accounting, ~~and certain book and tax differences related to utility plant items,~~ partially offset by state income ~~taxes~~taxes. See Notes 2 and 10 to the ~~provision~~financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for ~~uncertain tax positions.~~a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rates were ~~35.8%~~36.6% for the ~~second~~third quarter 2017 and ~~36.1%~~36.3% for the ~~six~~nine months ended ~~June~~September 30, 2017. The differences in the effective income tax rates for the ~~second~~third quarter 2017 and the ~~six~~nine months ended ~~June~~September 30, 2017 versus the federal statutory rate of 35% were primarily due to state income taxes and certain book and tax differences related to utility plant items, partially offset by flow-through tax accounting.

Income Tax Legislation

See the “Income Tax Legislation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for a discussion of the Tax Cuts and Jobs Act, the federal income tax legislation enacted in December 2017. Note 3 to the financial statements in the Form 10-K contains additional discussion of the effect of the Tax Act on 2017 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax ~~Act, and~~Act. Note 10 to the financial statements herein contains updates to that discussion. Note 2 to the financial statements herein and in the Form 10-K contains a discussion of proceedings commenced or other responses by Entergy and Entergy’s regulators to the Tax Act.

~~Liquidity and Capital Resources~~

~~Cash Flow~~

~~Cash flows for the six months ended June 30, 2018 and 2017 were as follows:~~

2018 2017
(In Thousands)
Cash and cash equivalents at beginning of period
$32,741

$103,068

Cash flow provided by (used in):
Operating activities 33,939
36,750
Investing activities (71,085 ) (49,005 )
Financing activities 4,431
(29,284 )
Net decrease in cash and cash equivalents (32,715 ) (41,539 )

Cash and cash equivalents at end of period
$26

$61,529

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Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2018 and 2017 were as follows:



	2018			2017
	(In Thousands)
Cash and cash equivalents at beginning of period		$32,741			$103,068

Cash flow provided by (used in):
Operating activities	100,327			84,240
Investing activities	(133,233		)	(116,704		)
Financing activities	33,085			(41,722		)
Net increase (decrease) in cash and cash equivalents	179			(74,186		)

Cash and cash equivalents at end of period		$32,920			$28,882

Operating Activities

Net cash flow provided by operating activities ~~decreased $2.8~~increased $16.1 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to the timing of ~~recovery of fuel and purchased power costs,~~payments to vendors, partially offset by the ~~timing~~return of ~~payments~~unprotected excess accumulated deferred income taxes to ~~vendors.~~customers. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

Investing Activities

Net cash flow used in investing activities increased ~~$22.1~~$16.5 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to to:

an increase of ~~$28.3~~$54.4 million in fossil-fueled generation construction expenditures primarily due to higher spending on the New Orleans Power Station project in ~~2018~~2018; and

an increase of ~~$12.5~~$14.2 million in distribution construction expenditures primarily due to a higher scope of work performed in 2018 as compared to the same period in 2017, including investment in the reliability and infrastructure of Entergy New Orleans’s distribution system.

The increase was partially offset by money pool activity and a $10.6 million decrease ~~of $12.7 million~~ in storm ~~spending.~~spending in 2018.

Decreases in Entergy New Orleans’s receivable from the money pool are a source of cash flow, and Entergy New Orleans’s receivable from the money pool decreased ~~$12.7~~$10.6 million infor the nine months ended September 30, 2018 compared to increasing ~~$1.7~~$32.1 million infor the nine months ended September 30, 2017. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Entergy New Orleans’s financing activities provided ~~$4.4~~$33.1 million of cash for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to using ~~$29.3~~$41.7 million of cash for the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to ~~money pool activity~~the issuance of $60 million of 4.51% Series first mortgage bonds in September 2018 and a decrease of ~~$9.7~~$12.4 million in common equity distributions in 2018 as compared to 2017. Common equity distributions were lower in 2018 primarily as a result of the construction of the New Orleans Power Station, as discussed below, and in anticipation of the excess accumulated deferred income taxes to be returned to customers as a result of the enactment of the Tax

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Cuts and Jobs Act in December 2017. See Note 2 to the financial statements herein and in the Form 10-K for discussion of regulatory proceedings related to the enactment of the Tax Cuts and Jobs Act.

~~Increases in Entergy New Orleans’s payable from the money pool are a source of cash flow, and Entergy New Orleans’s payable from the money pool increased $23.1 million in 2018.~~

Capital Structure

Entergy New Orleans’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio is primarily due to the issuance of long-term debt in 2018.


	June 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Debt to capital	50.1	%	51.3	%	52.6	%	51.3	%
Effect of excluding securitization bonds	(4.4	%)	(4.7	%)	(3.8	%)	(4.7	%)
Debt to capital, excluding securitization bonds (a)	45.7	%	46.6	%	48.8	%	46.6	%
Effect of subtracting cash	—	%	(2.4	%)	(2.0	%)	(2.4	%)
Net debt to net capital, excluding securitization bonds (a)	45.7	%	44.2	%	46.8	%	44.2	%


(a)	Calculation excludes the securitization bonds, which are non-recourse to Entergy New Orleans.

Net debt consists of debt less cash and cash equivalents. Debt consists of short-term borrowings, long-term debt, including the currently maturing portion, and the long-term payable due to an associated company. Capital consists of debt and common equity. Net capital consists of capital less cash and cash equivalents. Entergy New Orleans uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide

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useful information to its investors and creditors in evaluating Entergy New Orleans’s financial condition because the securitization bonds are non-recourse to Entergy New Orleans, as more fully described in Note 5 to the financial statements in the Form 10-K. Entergy New Orleans also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy New Orleans’s financial condition because net debt indicates Entergy New Orleans’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy New Orleans’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

Entergy New Orleans is developing its capital investment plan for 2019 through 2021 and currently anticipates making $600 million in capital investments during that period. The preliminary estimate includes amounts associated with specific investments such as the New Orleans Power Station, discussed below; transmission projects to enhance reliability, reduce congestion, and enable economic growth; distribution spending to enhance reliability and improve service to customers, including advanced meters and related investments; system improvements; software and security; and other investments. Estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints and requirements, environmental compliance, business opportunities, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital.

Entergy New Orleans’s receivables from ~~or (payables to)~~ the money pool were as follows:

June 30, 2018
December 31,
2017
June 30, 2017
December 31,
2016
(In Thousands)
($23,080) $12,723 $15,960 $14,215

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

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Entergy New Orleans has a credit facility in the amount of $25 million scheduled to expire in November 2018. The credit facility includes fronting commitments for the issuance of letters of credit against $10 million of the borrowing capacity of the facility. As of ~~June~~September 30, 2018, there were no cash borrowings and a $0.8 million letter of credit was outstanding under the facility. In addition, Entergy New Orleans is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of ~~June~~September 30, 2018, a ~~$7.4~~$2.1 million letter of credit was outstanding under Entergy New Orleans’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

Gas Infrastructure Rebuild Plan

As discussed in the Form 10-K, in September 2016, Entergy New Orleans submitted to the City Council a request for authorization for Entergy New Orleans to proceed with annual incremental capital funding of $12.5 million for its gas infrastructure rebuild plan and proposed that recovery of the investment be determined in connection with its next base rate case. The City Council authorized Entergy New Orleans to proceed with its replacement plans and established a schedule for proceedings in advance of the rate case intended to provide an opportunity for evaluation of the gas infrastructure plan that would best serve the public interest and the effect on customers of the approval of any such plan. In the course of that proceeding, the City Council’s advisors submitted pre-filed testimony recommending that Entergy New Orleans be allowed to continue with its conditioned-based approach to gas pipeline replacement to replace approximately 238 miles of low pressure pipe at a rate of approximately 25 miles per year. The City Council’s advisors also recommended that Entergy New Orleans be required to adhere to certain reporting requirements and recognized the need to address the sustained level of investment in gas infrastructure on customer bills. In September 2017, Entergy New Orleans filed rebuttal testimony suggesting that its recovery of future investment and customer effects would be addressed in the rate case that Entergy New Orleans was required to file in July 2018. The procedural schedule was suspended in order to allow for ~~amicable~~ resolution of the proceeding.

New Orleans Power Station

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approval to construct either the originally proposed 226 MW advanced combustion turbine, or alternatively, a 128 MW unit composed of natural gas-fired reciprocating engines and a related cost recovery plan. In March 2018 the City Council adopted a resolution approving construction of the 128 MW unit. The targeted commercial operation date is ~~January~~Spring 2020, subject to receipt of all necessary ~~permits.~~permits by the end of November 2018. In April 2018 intervenors opposing the construction of the New Orleans Power Station filed with the City Council a request for rehearing, which was subsequently denied, and a petition for judicial review of the City Council’s decision, and also filed a lawsuit challenging the City Council’s approval based on Louisiana’s open meeting law. In May 2018 the City Council announced that it would initiate an investigation into allegations that Entergy New Orleans, Entergy, or some other entity paid or participated in paying certain attendees and speakers in support of the New Orleans Power Station to attend or speak at certain meetings organized by the City Council. In June 2018, Entergy New Orleans produced documents in response to a City Council resolution relating to this investigation. The City Council issued a request for qualifications for an investigator and in June 2018 selected two investigators. In October 2018 the investigators for the City Council released their report, concluding that individuals were paid to attend and/or speak in support of the New Orleans Power Station and isthat Entergy New Orleans “knew or should have known that such conduct occurred or reasonably might occur.” The City Council held a special meeting on October 31, 2018 to allow the investigators to present the report and for the City Council to consider next steps. At that meeting, the City Council issued a resolution requiring Entergy New Orleans to show cause why it should not be fined $5 million as a result of the findings in the ~~process~~report. A response to the resolution is due within 30 days from issuance of ~~contracting~~the certified resolution. Entergy New Orleans disagrees with ~~them~~certain characterizations and omissions of fact in the report and submitted its response to ~~conduct~~ the ~~investigation.~~City Council.

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Renewables

In July 2018, Entergy New Orleans filed an application with the City Council requesting approval of three utility-scale solar projects totaling 90 MW. If approved, the resource additions will allow Entergy New Orleans to make significant progress towards meeting its voluntary commitment to the City Council to add up to 100 MW of renewable energy resources. The three projects include constructing a self-build solar plant in Orleans Parish with an output of 20 MW, acquiring a 50 MW solar facility in Washington Parish through a build-own-transfer acquisition, and procuring 20 MW of solar power from a project to be built in St. James Parish through a power purchase agreement. ~~Entergy New Orleans requested~~In August 2018 the City Council ~~approval following~~approved a ~~six-month~~ procedural schedule ~~which, if granted, would allow the various projects~~opening discovery that is designed to ~~come online from 2020 to 2021.~~ encourage settlement by December 2018.

Advanced Metering Infrastructure (AMI) Filings

State and Local Rate Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – State and Local Rate Regulation” in the Form 10-K for a discussion of state and local rate regulation. The following are updates to that discussion.

Retail Rates

Energy Smart Programs

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million of benefits resulting from the Tax Act to Energy Smart. Entergy New Orleans is seeking approval of a permanent and stable source of funding for Energy Smart as part of its base rate case filed in July 2018 and revised in September 2018.

Base Rate Case

In July 2018, Entergy New Orleans filed its 2018 base rate case with the City ~~Council.~~Council, but withdrew it in August 2018. In September 2018, Entergy New ~~Orleans’s application supports~~Orleans filed a ~~$20~~revised electric and gas base rate case with the City Council. The revised filing requests a 10.5% return on equity for electric operations with opportunity to earn a 10.75% return on equity through a performance adder provision of the electric formula rate plan, and requests a 10.75% return on equity for gas operations. The proposed electric rates in the revised filing reflect a net reduction of $20.3 million. The reduction in electric rates includes a base rate increase of $135.2 million, of which $131.5 million is associated with moving costs currently collected through fuel and riders into base rates, plus a request for an advanced metering

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Entergy New Orleans, LLC and Subsidiaries

Management's Financial Discussion and Analysis

surcharge to recover $7.1 million associated with advanced metering infrastructure, offset by a net decrease ~~in total revenue requirement.~~of $31.1 million related to projected fuel and energy efficiency riders. The filing also includes a proposed gas rate decrease of $142 thousand. Entergy New Orleans’s rates reflect the inclusion of federal income tax reductions due to the Tax Act and the provisions of a ~~previously approved~~previously-approved agreement in principle determining how the benefits of the Tax Act would flow. Entergy New Orleans included cost of service studies for electric and gas operations for the twelve months ending December 31, 2017 and the projected twelve months ending December 31, 2018. In addition, Entergy New Orleans included capital additions expected to be placed into service for the period through December 31, 2019. Entergy New Orleans’s request for a change in rates is based on the projected twelve months ending December 31, 2018. ~~For~~

The filing’s major provisions include: (1) a new electric ~~rates, that results in a proposed decrease of total~~rate structure, which realigns the revenue requirement ~~of approximately $20 million. For gas rates, that results in a proposed decrease of $129 thousand.~~

Entergy New Orleans has requested to restructure electric rates to take into account the addition of electric operations in Algiers, such that a single set of rates will be charged in the City of New Orleans, including an increase in its electric customer charges. Entergy New Orleans’s request also includes: a 10.75% return on equity; a three-year formula rate plan for electric (with decoupling) and gas operations, eachassociated with ~~a 100 basis point bandwidth (i.e., 10.75% +/- 50 basis points); realignment of~~ capacity and long-term service agreement expense from certain existing riders to base ~~rates; implementation of riders~~revenue, provides for ~~1) contemporaneous~~the recovery of ~~net~~the cost of advanced metering infrastructure, 2)and partially blends rates for Entergy New Orleans’s customers residing in Algiers with customers residing in the remainder of Orleans Parish through a three-year phase-in; (2) contemporaneous ~~true-up~~cost recovery riders for ~~existing capacity and~~ investments in energy efficiency/demand response, incremental changes in capacity/long-term service agreement ~~expense, as well as new capacity such as power purchase agreements and battery storage (through the purchased power capacity and acquisition cost recovery rider), 3) recovery of distribution~~costs, grid modernization investment, and gas infrastructure replacement ~~program,~~investment; and ~~interim energy efficiency, and 4) permanent recovery mechanism~~(3) formula rate plans for demand-side management activities, including putting into rate base the costs of demand side management activities and contemporaneous recovery of lost contribution to fixed costs; new depreciation rates forboth electric and gas assets; and proposed implementation of new voluntary customer offerings (such as green power, fixed bill, community solar, pre-pay electric and gas service, and electric vehicle charging infrastructure options).operations. The procedural schedule calls for an evidentiary hearing to be held in June 2019.

Reliability Investigation

In August 2017 the City Council established a docket to investigate the reliability of the Entergy New Orleans distribution system and to consider implementing certain reliability standards and possible financial penalties for not meeting any such standards. In April 2018 the City Council adopted a resolution directing Entergy New Orleans to demonstrate that it has been prudent in the management and maintenance of the reliability of its distribution system. The resolution also called for Entergy New Orleans to file a revised reliability plan addressing the current state of its distribution system and proposing remedial measures for increasing reliability. In June 2018, Entergy New Orleans filed its response to the City Council’s resolution regarding the prudence of its management and maintenance of the reliability of its distribution system. In July 2018, Entergy New Orleans filed its revised reliability plan discussing the various reliability programs that it uses to improve distribution system reliability and discussing generally the positive effect that advanced meter deployment and grid modernization can have on future reliability. Entergy New Orleans ~~will hold~~has retained a ~~technical conference~~national consulting firm with expertise in distribution system reliability to conduct a review of Entergy New Orleans’s distribution system reliability-related practices and procedures and to provide recommendations for improving distribution system reliability. The report was filed with the City Council ~~advisors~~in October 2018. The City Council also approved a resolution that opens a prudence investigation into whether Entergy New Orleans was imprudent for not acting sooner to address outages in New Orleans and ~~other parties to discuss reliability issues and answer questions.~~whether fines should be imposed.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation.

~~150~~

~~Table of Contents~~

~~Entergy New Orleans, LLC and Subsidiaries~~

~~Management's Financial Discussion and Analysis~~

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for further discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

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Table of Contents

Entergy New Orleans, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy New Orleans’s accounting for utility regulatory accounting, unbilled revenue, impairment of long-lived assets and trust fund investments, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of new accounting pronouncements.

																										ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES	CONSOLIDATED INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2018 and 2017
For the Three and Nine Months Ended September 30, 2018 and 2017													For the Three and Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Three Months Ended						Six Months Ended							Three Months Ended						Nine Months Ended
	2018			2017			2018			2017				2018			2017			2018			2017
	(In Thousands)						(In Thousands)							(In Thousands)						(In Thousands)
OPERATING REVENUES
Electric		$159,602			$157,455			$315,420			$299,800				$184,164			$182,451			$499,584			$482,251
Natural gas	18,844			18,767			51,301			45,411				16,018			16,566			67,319			61,977
TOTAL	178,446			176,222			366,721			345,211				200,182			199,017			566,903			544,228

OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	15,366			22,961			39,105			53,036				54,754			26,082			93,859			79,118
Purchased power	73,789			73,105			156,945			141,464				57,828			79,137			214,773			220,601
Other operation and maintenance	28,420			25,079			56,719			47,369				30,593			26,092			87,312			73,462
Taxes other than income taxes	12,851			13,416			27,983			26,262				15,551			15,135			43,534			41,397
Depreciation and amortization	13,950			13,020			27,697			26,070				14,059			13,286			41,756			39,356
Other regulatory charges - net	6,127			818			12,460			1,203				5,853			5,514			18,313			6,717
TOTAL	150,503			148,399			320,909			295,404				178,638			165,246			499,547			460,651

OPERATING INCOME	27,943			27,823			45,812			49,807				21,544			33,771			67,356			83,577

OTHER INCOME
Allowance for equity funds used during construction	1,217			552			2,068			1,002				1,694			654			3,762			1,656
Interest and investment income	207			164			300			299				30			222			330			521
Miscellaneous - net	(1,404		)	(177		)	(1,741		)	(301		)		(660		)	(317		)	(2,401		)	(617		)
TOTAL	20			539			627			1,000				1,064			559			1,691			1,560

INTEREST EXPENSE
Interest expense	5,269			5,356			10,548			10,699				5,388			5,313			15,936			16,012
Allowance for borrowed funds used during construction	(450		)	(193		)	(764		)	(351		)		(626		)	(229		)	(1,390		)	(580		)
TOTAL	4,819			5,163			9,784			10,348				4,762			5,084			14,546			15,432

INCOME BEFORE INCOME TAXES	23,144			23,199			36,655			40,459				17,846			29,246			54,501			69,705

Income taxes	4,875			8,317			7,504			14,599				(3,561		)	10,717			3,943			25,316

NET INCOME	18,269			14,882			29,151			25,860				21,407			18,529			50,558			44,389

Preferred dividend requirements and other	—			241			—			482				—			241			—			724

EARNINGS APPLICABLE TO COMMON EQUITY		$18,269			$14,641			$29,151			$25,378				$21,407			$18,288			$50,558			$43,665

See Notes to Financial Statements.

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														ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES	CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2018 and 2017
For the Nine Months Ended September 30, 2018 and 2017							For the Nine Months Ended September 30, 2018 and 2017
(Unaudited)
	2018			2017				2018			2017
	(In Thousands)							(In Thousands)
OPERATING ACTIVITIES
Net income		$29,151			$25,860				$50,558			$44,389
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization	27,697			26,070				41,756			39,356
Deferred income taxes, investment tax credits, and non-current taxes accrued	22,813			14,764				25,605			30,834
Changes in assets and liabilities:
Receivables	(10,930		)	(5,979		)		(15,310		)	(17,030		)
Fuel inventory	1,833			(465		)		495			(490		)
Accounts payable	5,073			(8,761		)		8,868			(4,950		)
Prepaid taxes	(10,602		)	38				(8,743		)	(4,484		)
Interest accrued	(459		)	(469		)		564			546
Deferred fuel costs	(27,056		)	2,087				(59		)	4,258
Other working capital accounts	(9,524		)	(11,774		)		(5,062		)	(6,750		)
Provisions for estimated losses	438			(1,794		)		417			(1,702		)
Other regulatory assets	11,957			2,719				19,068			10,093
Other regulatory liabilities	3,042			(610		)		(5,353		)	(1,131		)
Pension and other postretirement liabilities	(7,725		)	(8,049		)		(12,956		)	(13,793		)
Other assets and liabilities	(1,769		)	3,113				479			5,094
Net cash flow provided by operating activities	33,939			36,750				100,327			84,240

INVESTING ACTIVITIES
Construction expenditures	(85,324		)	(48,683		)		(142,585		)	(81,143		)
Allowance for equity funds used during construction	2,068			1,002				3,762			1,656
Changes in money pool receivable - net	12,723			(1,745		)		10,607			(32,067		)
Receipts from storm reserve escrow account	3			—				3			—
Payments to storm reserve escrow account	(544		)	(235		)		(905		)	(406		)
Changes in securitization account	(11		)	656				(4,115		)	(2,990		)
Change in other investments								—			(1,754		)
Net cash flow used in investing activities	(71,085		)	(49,005		)		(133,233		)	(116,704		)

FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt								59,590			—
Retirement of long-term debt	(5,342		)	(5,114		)		(5,342		)	(5,114		)
Change in money pool payable - net	23,080			—
Dividends paid:
Common stock	(14,500		)	(24,150		)
Distributions/dividends paid:
Common equity								(23,750		)	(36,100		)
Preferred stock	—			(482		)		—			(724		)
Other	1,193			462				2,587			216
Net cash flow provided by (used in) financing activities	4,431			(29,284		)		33,085			(41,722		)

Net decrease in cash and cash equivalents	(32,715		)	(41,539		)
Net increase (decrease) in cash and cash equivalents								179			(74,186		)
Cash and cash equivalents at beginning of period	32,741			103,068				32,741			103,068
Cash and cash equivalents at end of period		$26			$61,529				$32,920			$28,882

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized		$10,483			$10,637				$14,584			$14,668

See Notes to Financial Statements.

														ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES	CONSOLIDATED BALANCE SHEETS	ASSETS
June 30, 2018 and December 31, 2017
September 30, 2018 and December 31, 2017							September 30, 2018 and December 31, 2017
(Unaudited)
	2018			2017				2018			2017
	(In Thousands)							(In Thousands)
CURRENT ASSETS
Cash and cash equivalents
Cash		$26			$30				$26			$30
Temporary cash investments	—			32,711				32,894			32,711
Total cash and cash equivalents	26			32,741				32,920			32,741
Securitization recovery trust account	1,466			1,455				5,570			1,455
Accounts receivable:
Customer	58,918			51,006				61,107			51,006
Allowance for doubtful accounts	(3,068		)	(3,057		)		(3,135		)	(3,057		)
Associated companies	10,013			22,976				17,464			22,976
Other	5,283			6,471				5,986			6,471
Accrued unbilled revenues	25,095			20,638				21,315			20,638
Total accounts receivable	96,241			98,034				102,737			98,034
Deferred fuel costs	19,282			—
Fuel inventory - at average cost	57			1,890				1,395			1,890
Materials and supplies - at average cost	12,267			10,381				12,944			10,381
Prepaid taxes	37,081			26,479				35,222			26,479
Prepayments and other	17,602			8,030				11,160			8,030
TOTAL	184,022			179,010				201,948			179,010

OTHER PROPERTY AND INVESTMENTS
Non-utility property at cost (less accumulated depreciation)	1,016			1,016				1,016			1,016
Storm reserve escrow account	80,087			79,546				80,448			79,546
Other	—			2,373				—			2,373
TOTAL	81,103			82,935				81,464			82,935

UTILITY PLANT
Electric	1,323,666			1,302,235				1,334,227			1,302,235
Natural gas	273,913			261,263				279,689			261,263
Construction work in progress	88,104			46,993				139,839			46,993
TOTAL UTILITY PLANT	1,685,683			1,610,491				1,753,755			1,610,491
Less - accumulated depreciation and amortization	647,582			631,178				659,315			631,178
UTILITY PLANT - NET	1,038,101			979,313				1,094,440			979,313

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Deferred fuel costs	4,080			4,080				4,080			4,080
Other regulatory assets (includes securitization property of $66,475 as of June 30, 2018 and $72,095 as of December 31, 2017)	239,476			251,433
Other regulatory assets (includes securitization property of $62,857 as of September 30, 2018 and $72,095 as of December 31, 2017)								232,365			251,433
Other	1,841			1,065				1,471			1,065
TOTAL	245,397			256,578				237,916			256,578

TOTAL ASSETS		$1,548,623			$1,497,836				$1,615,768			$1,497,836

See Notes to Financial Statements.

										ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES	CONSOLIDATED BALANCE SHEETS	LIABILITIES AND EQUITY
June 30, 2018 and December 31, 2017
September 30, 2018 and December 31, 2017					September 30, 2018 and December 31, 2017
(Unaudited)
	2018		2017			2018		2017
	(In Thousands)					(In Thousands)
CURRENT LIABILITIES
Payable due to associated company		$2,077		$2,077			$2,077		$2,077
Accounts payable:
Associated companies	63,887		47,472			35,094		47,472
Other	43,766		29,777			67,197		29,777
Customer deposits	28,622		28,442			28,617		28,442
Interest accrued	5,028		5,487			6,051		5,487
Deferred fuel costs	—		7,774			7,715		7,774
Current portion of unprotected excess accumulated deferred income taxes	32,464		—			26,200		—
Other	8,749		7,351			7,459		7,351
TOTAL CURRENT LIABILITIES	184,593		128,380			180,410		128,380

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	305,210		283,302			310,767		283,302
Accumulated deferred investment tax credits	2,269		2,323			2,242		2,323
Regulatory liability for income taxes - net	83,499		119,259			78,164		119,259
Asset retirement cost liabilities	3,182		3,076			3,236		3,076
Accumulated provisions	85,521		85,083			85,500		85,083
Pension and other postretirement liabilities	13,013		20,755			7,774		20,755
Long-term debt (includes securitization bonds of $69,199 as of June 30, 2018 and $74,419 as of December 31, 2017)	413,372		418,447
Long-term debt (includes securitization bonds of $69,259 as of September 30, 2018 and $74,419 as of December 31, 2017)						473,147		418,447
Long-term payable due to associated company	16,346		16,346			16,346		16,346
Other	11,419		5,317			15,826		5,317
TOTAL NON-CURRENT LIABILITIES	933,831		953,908			993,002		953,908

Commitments and Contingencies

EQUITY
Member's equity	430,199		415,548			442,356		415,548
TOTAL	430,199		415,548			442,356		415,548

TOTAL LIABILITIES AND EQUITY		$1,548,623		$1,497,836			$1,615,768		$1,497,836

See Notes to Financial Statements.



ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the ~~Six~~Nine Months Ended ~~June~~September 30, 2018 and 2017
(Unaudited)


	Member’s Equity
	(In Thousands)

Balance at December 31, 2016		$426,946

Net income	~~25,860~~44,389
Common equity distributions	(~~24,150~~36,100		)
Preferred stock dividends	(~~482~~724		)

Balance at ~~June~~September 30, 2017		$~~428,174~~434,511


Balance at December 31, 2017		$415,548

Net income	~~29,151~~50,558
Common equity distributions	(~~14,500~~23,750		)

Balance at ~~June~~September 30, 2018		$~~430,199~~442,356

See Notes to Financial Statements.

																				ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES	SELECTED OPERATING RESULTS
For the Three and Six Months Ended June 30, 2018 and 2017
For the Three and Nine Months Ended September 30, 2018 and 2017										For the Three and Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Three Months Ended				Increase/						Three Months Ended				Increase/
Description	2018		2017		(Decrease)			%			2018		2017		(Decrease)			%
	(Dollars In Millions)										(Dollars In Millions)
Electric Operating Revenues:
Residential		$58		$56		$2		4				$86		$82		$4		5
Commercial	55		56		(1		)	(2	)		62		63		(1		)	(2	)
Industrial	9		9		—			—			10		9		1			11
Governmental	18		19		(1		)	(5	)		20		21		(1		)	(5	)
Total billed retail	140		140		—			—			178		175		3			2
Sales for resale:
Non-associated companies	6		9		(3		)	(33	)		5		3		2			67
Other	14		8		6			75			1		4		(3		)	(75	)
Total		$160		$157		$3		2				$184		$182		$2		1

Billed Electric Energy Sales (GWh):
Residential	490		468		22			5			779		711		68			10
Commercial	527		541		(14		)	(3	)		660		634		26			4
Industrial	111		105		6			6			128		119		9			8
Governmental	185		188		(3		)	(2	)		225		217		8			4
Total retail	1,313		1,302		11			1			1,792		1,681		111			7
Sales for resale:
Non-associated companies	310		508		(198		)	(39	)		281		255		26			10
Total	1,623		1,810		(187		)	(10	)		2,073		1,936		137			7


	Six Months Ended				Increase/						Nine Months Ended				Increase/
Description	2018		2017		(Decrease)			%			2018		2017		(Decrease)			%
	(Dollars In Millions)										(Dollars In Millions)
Electric Operating Revenues:
Residential		$123		$109		$14		13				$209		$191		$18		9
Commercial	109		110		(1		)	(1	)		171		173		(2		)	(1	)
Industrial	17		17		—			—			26		26		—			—
Governmental	36		37		(1		)	(3	)		57		58		(1		)	(2	)
Total billed retail	285		273		12			4			463		448		15			3
Sales for resale:
Non associated companies	19		18		1			6			24		21		3			14
Other	11		9		2			22			12		13		(1		)	(8	)
Total		$315		$300		$15		5				$499		$482		$17		4

Billed Electric Energy Sales (GWh):
Residential	1,067		924		143			15			1,846		1,635		211			13
Commercial	1,051		1,056		(5		)	—			1,711		1,690		21			1
Industrial	210		203		7			3			338		322		16			5
Governmental	366		372		(6		)	(2	)		591		589		2			—
Total retail	2,694		2,555		139			5			4,486		4,236		250			6
Sales for resale:
Non-associated companies	937		1,015		(78		)	(8	)		1,218		1,270		(52		)	(4	)
Total	3,631		3,570		61			2			5,704		5,506		198			4

ENTERGY TEXAS, INC. AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

~~Second~~Third Quarter2018 Compared to ~~Second~~Third Quarter2017

Net income increased $26.3 million primarily due to higher net revenue and a lower effective income tax rate, partially offset by higher other operation and maintenance expenses.

Nine Months Ended September 30, 2018 Compared to Nine Months Ended September 30, 2017

Net income increased ~~$9.7~~$42.4 million primarily due to higher net revenue and a lower effective income tax rate, partially offset by higher other operation and maintenance expenses and higher depreciation and amortization expenses.

~~Six Months Ended June 30, 2018 Compared to Six Months Ended June 30, 2017~~

Net income increased $16.2 million primarily due to higher net revenue and a lower effective income tax rate, partially offset by higher taxes other than income taxes, higher other operation and maintenance expenses, and higher depreciation and amortization expenses.

Net Revenue

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter 2017



	Amount
	(In Millions)
2017 net revenue		$~~153.0~~181.5
Volume/weather	~~12.1~~13.6
Purchased power capacity	~~4.5~~10.9
Retail electric price	3.3
Other	~~0.3~~1.6
2018 net revenue		$~~169.9~~210.9

The volume/weather variance is primarily due to an increase of ~~137~~420 GWh, or 3%8%, in billed electricity usage, including the effect of more favorable weather on residential and commercial sales and an increase in commercial and industrial usage. The increase in commercial usage is primarily due to the effects of the power outages caused by Hurricane Harvey, which decreased sales volume in 2017. The increase in industrial usage is primarily due to new customers in the chemicals and wood products industries and an increase in demand ~~for cogeneration customers and~~from mid-size to small customers.

The purchased power capacity variance is primarily due to decreased purchased power capacity costs under Entergy Texas’s purchased power agreements with Entergy Louisiana.

~~Six~~The retail electric price variance is primarily due to an increase in the distribution cost recovery factor rider rate in September 2017, as approved by the PUCT. See Note 2 to the financial statements in the Form 10-K for further discussion of the distribution cost recovery factor rider filing.

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Entergy Texas, Inc. and Subsidiaries

Management's Financial Discussion and Analysis

Nine Months Ended ~~June~~September 30, 2018 Compared to ~~Six~~Nine Months Ended ~~June~~September 30, 2017

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges. Following is an analysis of the change in net revenue comparing the ~~six~~nine months ended ~~June~~September 30, 2018 to the ~~six~~nine months ended ~~June~~September 30, 2017:

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	Amount
	(In Millions)
2017 net revenue		$~~293.3~~474.8
Volume/weather	~~17.0~~30.6
Retail electric price	~~7.1~~10.4
Purchased power capacity	9.5
Other	~~(2.5~~0.4		)
2018 net revenue		$~~314.9~~525.7

The volume/weather variance is primarily due to an increase of ~~524~~944 GWh, or 6%7%, in billed electricity usage, including the effect of more favorable weather on residential and commercial sales and an increase in commercial and industrial usage. The increase ~~was partially offset~~in commercial usage is primarily due to the effects of the power outages caused by Hurricane Harvey, which decreased ~~usage during the unbilled~~ sales ~~period.~~volume in 2017. The increase in industrial usage is primarily due to an increase in demand ~~for~~from mid-size to small customers and new customers in the chemicals and wood products industries.

The retail electric price variance is primarily due to increases in the transmission cost recovery factor rider rate in March 2017 and the distribution cost recovery factor rider rate in September 2017, each as approved by the PUCT. See Note 2 to the financial statements in the Form 10-K for further discussion of the transmission cost recovery factor rider and the distribution cost recovery factor rider filings.

The purchased power capacity variance is primarily due to decreased purchased power capacity costs under Entergy Texas’s purchased power agreements with Entergy Louisiana.

Other Income Statement Variances

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter 2017

Other operation and maintenance expenses increased primarily due to to:

an increase of ~~$2.5~~$2.7 million in energy efficiency costs primarily due to the timing of recovery from customers;

an increase of $1.5 million in fossil-fueled generation expenses primarily due to aan overall higher scope of work performed ~~during plant outages~~in the third quarter 2018 as compared to the same period in 2017;

an increase of $1.3 million in customer service costs primarily due to higher contract costs and write-offs of customer accounts;

an increase of $1 million in information technology costs primarily due to higher software maintenance costs and higher contract costs; and

an increase of $1 million in distribution operations costs primarily due to the timing of work performed and an overall higher scope of work performed in 2018 as compared to the same period in 2017.

~~Depreciation and amortization expenses increased primarily due to additions to plant~~The increase was partially offset by a gain on the sale of assets in ~~service.~~2018 of $2.1 million.

~~Six~~

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Nine Months Ended ~~June~~September 30, 2018 Compared to ~~Six~~Nine Months Ended ~~June~~September 30, 2017

Other operation and maintenance expenses increased primarily due to to:

an increase of ~~$2.3~~$3.8 million in fossil-fueled generation expenses primarily due to aan overall higher scope of work performed ~~during plant outages~~ in 2018 as compared to the same period in ~~2017.~~2017;

~~Taxes other than income taxes increased~~an increase of $3.2 million in energy efficiency costs primarily due to the timing of recovery from customers;

an increase of $3.1 million in ~~ad valorem taxes resulting from~~distribution operations costs primarily due to the timing of work performed and an overall higher ~~assessments.~~scope of work performed in 2018 as compared to the same period in 2017; and

an increase of $1.9 million in customer service costs primarily due to higher contract costs and write-offs of customer accounts.

The increase was partially offset by a gain on the sale of assets in 2018 of $2.1 million.

Depreciation and amortization expenses increased primarily due to additions to plant in service.

Income Taxes

The effective income tax rate was ~~22%~~20.4% for the ~~second~~third quarter 2018. The difference in the effective income tax rate for the ~~second~~third quarter 2018 versus the federal statutory rate of 21% was primarily due to ~~an IRS audit settlement for the 2012-2013~~book and tax ~~returns. See Note 10~~differences related to the ~~financial statements herein~~allowance for ~~a discussion of the IRS audit settlement.~~equity funds used during construction and certain book and tax differences related to utility plant items.

The effective income tax rate was ~~22.1%~~21.1% for the ~~six~~nine months ended ~~June~~September 30, 2018. The difference in the effective income tax rate for the ~~six~~nine months ended ~~June~~September 30, 2018 versus the federal statutory rate of 21% was primarily due to a write-off of a stock-based compensation deferred tax asset in ~~2018.~~

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~~Management's Financial Discussion and Analysis~~

The effective income tax rate was 26.2% for the second quarter 2017. The difference in the effective income tax rate for the second quarter 2017 versus the federal statutory rate of 35% was primarily due to the reversal of a portion of the provision for uncertain tax positions, ~~and~~partially offset by book and tax differences related to the allowance for equity funds used during construction ~~partially offset by~~and certain book and tax differences related to utility plant items.

The effective income tax rate was 35.9% for the third quarter 2017. The difference in the effective income tax rate for the third quarter 2017 versus the federal statutory rate of 35% was primarily due to certain book and tax differences related to utility plant items, partially offset by book and tax differences related to the allowance for equity funds used during construction.

The effective income tax rate was ~~33%~~34.6% for the ~~six~~nine months ended ~~June~~September 30, 2017. The difference in the effective income tax rate for the ~~six~~nine months ended ~~June~~September 30, 2017 versus the federal statutory rate of 35% was primarily due to ~~the reversal of a portion of the provision for uncertain tax positions and~~ book and tax differences related to the allowance for equity funds used during construction and the reversal of a portion of the provision for uncertain tax positions, partially offset by certain book and tax differences related to utility plant items and a write-off of a stock-based compensation deferred tax asset.

Income Tax Legislation

See the “Income Tax Legislation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for a discussion of the Tax Cuts and Jobs Act, the federal income tax legislation enacted in December 2017. Note 3 to the financial statements in the Form 10-K contains additional discussion of the effect of the Tax Act on 2017 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax ~~Act, and~~Act. Note 10 to the financial statements herein contains updates to that discussion. Note 2 to the financial statements herein and in the Form 10-K contains a discussion of proceedings commenced or other responses by Entergy and Entergy’s regulators to the Tax Act.

~~Liquidity and Capital Resources~~

~~Cash Flow~~

~~Cash flows for the six months ended June 30, 2018 and 2017 were as follows:~~

2018 2017
(In Thousands)
Cash and cash equivalents at beginning of period
$115,513

$6,181

Cash flow provided by (used in):
Operating activities 90,479
132,397
Investing activities (124,925 ) (140,929 )
Financing activities (40,668 ) 3,416
Net decrease in cash and cash equivalents (75,114 ) (5,116 )

Cash and cash equivalents at end of period
$40,399

$1,065

~~Operating Activities~~

Net cash flow provided by operating activities decreased $41.9 million for the six months ended June 30, 2018 compared to the six months ended June 30, 2017 primarily due to the timing of recovery of fuel and purchased power costs.

~~Investing Activities~~

Net cash flow used in investing activities decreased $16 million for the six months ended June 30, 2018 compared to the six months ended June 30, 2017 primarily due to money pool activity and a decrease of $5.2 million in distribution construction expenditures primarily due to a lower scope of work performed in 2018 as compared to the same period in 2017. The decrease was partially offset by:

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Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2018 and 2017 were as follows:



	2018			2017
	(In Thousands)
Cash and cash equivalents at beginning of period		$115,513			$6,181

Cash flow provided by (used in):
Operating activities	197,677			192,954
Investing activities	(233,850		)	(228,582		)
Financing activities	(58,843		)	30,949
Net decrease in cash and cash equivalents	(95,016		)	(4,679		)

Cash and cash equivalents at end of period		$20,497			$1,502

Operating Activities

Net cash flow provided by operating activities increased $4.7 million for the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017 primarily due to increased net income, partially offset by the timing of recovery of fuel and purchased power costs and the timing of collection of receivables from customers.

Investing Activities

Net cash flow used in investing activities increased $5.3 million for the nine months ended September 30, 2018 compared to the nine months ended September 30, 2017 primarily due to an increase of ~~$14.2~~$48.8 million in fossil-fueled generation construction expenditures primarily due to increased spending on the Montgomery County Power ~~Station and a higher scope of work performed in 2018 as compared to the same period in 2017; and~~

anStation. The increase ~~of $4.4 million in transmission construction expenditures primarily due to a higher scope of work performed in 2018 as compared to the same period in 2017.~~was partially offset by money pool activity.

Decreases in Entergy Texas’s receivable from the money pool are a source of cash flow, and Entergy Texas’s receivable from the money pool decreased by ~~$34.9~~$43.7 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to decreasing by $0.7 million for the ~~six~~nine months ended ~~June~~September 30, 2017. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Entergy Texas’s financing activities used ~~$40.7~~$58.8 million of cash for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to providing ~~$3.4~~$30.9 million of cash for the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to money pool activity. ~~See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.~~

Increases in Entergy Texas’s payable to the money pool are a source of cash flow, and Entergy Texas’s payable to the money pool increased by ~~$39.2~~$89.3 million for the ~~six~~nine months ended ~~June~~September 30, 2017.

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Capital Structure

Entergy Texas’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio for Entergy Texas is primarily due to the increase in retained earnings.


	June 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Debt to capital	54.2	%	55.7	%	52.6	%	55.7	%
Effect of excluding the securitization bonds	(5.8	%)	(6.3	%)	(5.4	%)	(6.3	%)
Debt to capital, excluding securitization bonds (a)	48.4	%	49.4	%	47.2	%	49.4	%
Effect of subtracting cash	(0.8	%)	(2.5	%)	(0.4	%)	(2.5	%)
Net debt to net capital, excluding securitization bonds (a)	47.6	%	46.9	%	46.8	%	46.9	%


(a)	Calculation excludes the securitization bonds, which are non-recourse to Entergy Texas.

Net debt consists of debt less cash and cash equivalents. Debt consists of long-term debt, including the currently maturing portion. Capital consists of debt and common equity. Net capital consists of capital less cash and cash equivalents. Entergy Texas uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy Texas’s financial condition because the securitization bonds are non-recourse to Entergy Texas, as more fully described in Note 5 to the financial statements in the Form 10-K. Entergy Texas also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Texas’s financial condition because net debt indicates Entergy Texas’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Texas’s uses and sources of capital. Following are updates to information provided in the Form 10-K.

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Entergy Texas ~~Inc.~~is developing its capital investment plan for 2019 through 2021 and ~~Subsidiaries~~

~~Management's Financial Discussion~~currently anticipates making $1.9 billion in capital investments during that period. The preliminary estimate includes amounts associated with specific investments such as Montgomery County Power Station; transmission projects to enhance reliability, reduce congestion, and ~~Analysis~~

enable economic growth; distribution spending to enhance reliability and improve service to customers, including advanced meters and related investments; system improvements; software and security; and other investments. Estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints and requirements, environmental compliance, business opportunities, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital.

Entergy Texas’s receivables from or (payables to) the money pool were as follows:

June 30,
2018
December 31,
2017

June 30,
2017

December 31,
2016
(In Thousands)
$10,001 $44,903 ($39,222) $681

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy Texas has a credit facility in the amount of $150 million scheduled to expire in ~~August 2022.~~September 2023. The credit facility includes fronting commitments for the issuance of letters of credit against $30 million of the borrowing

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capacity of the facility. As of ~~June~~September 30, 2018, there were no cash borrowings and ~~$24.4~~$1.3 million of letters of credit outstanding under the credit facility. In addition, Entergy Texas is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of ~~June~~September 30, 2018, a ~~$12.5~~$20 million letter of credit was outstanding under Entergy Texas’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - State and Local Rate Regulation and Fuel-Cost Recovery” in the Form 10-K for a discussion of state and local rate regulation and fuel-cost recovery. The following are updates to that discussion.

Fuel and purchased power cost recovery

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 of the Federal District Court ruling to the U.S. Court of Appeals for the Fifth Circuit. Oral argument was held before the Fifth Circuit in February 2018. In April 2018 the Fifth Circuit reversed the decision of the Federal District Court, reinstating the original PUCT decision. ~~The~~In October 2018, Entergy Texas filed a notice of nonsuit of its claims in the State District ~~Court~~Court’s appeal of the PUCT’s January 2016 ~~decision remains pending.~~decision.

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.

2018 Base Rate Case

InIn May 2018, Entergy Texas filed a base rate case with the PUCT seeking an increase in base rates and rider rates of approximately $166 million, of which $48 million is associated with moving costs currently being collected through riders into base rates such that the total incremental revenue requirement increase is approximately $118 million. Entergy Texas’s proposed rates and revenues reflect the inclusion of federal income tax reductions due to the Tax Act as well as a rider designed to return ~~approximately $202 million of~~ unprotected excess accumulated deferred

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~~federal~~ income taxes over a period of two years following PUCT approval. The base rate case is based on a 12-month test year ending December 31, 2017. In addition, Entergy Texas included capital additions placed into service for the period of April 1, 2013 through December 31, 2017, as well as a post-test year adjustment to include capital additions placed in service by June 30, 2018. ~~A hearing~~In October 2018 the parties filed an unopposed settlement resolving all issues in the proceeding, supporting testimony, a proposed order approving the settlement, and a motion for interim rates effective for usage on and after October 17, 2018. The unopposed settlement reflects the ~~merits~~following terms: a base rate increase of $53.2 million (net of costs realigned from riders), a $25 million refund to reflect the lower federal income tax rate applicable to Entergy Texas from January 25, 2018 through the date new rates are implemented, $6 million of capitalized skylining tree hazard costs will not be recovered from customers, $242.5 million of protected excess accumulated deferred income taxes, which includes a tax gross-up, will be returned to customers through base rates under the average rate assumption method over the lives of the associated assets, and $185.2 million of unprotected excess accumulated deferred income

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taxes, which includes a tax gross-up, will be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider will include carrying charges and will be in effect over a period of 12 months for large industrial customers and over a period of four years for other customers. The settlement, if approved by the PUCT, would provide final resolution of all issues in the matter, including those related to the Tax Act. In October 2018 the ALJ granted the unopposed motion for interim rates to be effective for service rendered on or after October 17, 2018. The unopposed settlement is ~~scheduled in August 2018.~~pending consideration by the PUCT.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation.

Industrial and Commercial Customers

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Industrial and Commercial Customers” in the Form 10-K for a discussion of industrial and commercial customers.

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of utility regulatory accounting, unbilled revenue, impairment of long-lived assets and trust fund investments, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of new accounting pronouncements.

																										ENTERGY TEXAS, INC. AND SUBSIDIARIES	CONSOLIDATED INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2018 and 2017
For the Three and Nine Months Ended September 30, 2018 and 2017													For the Three and Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Three Months Ended						Six Months Ended							Three Months Ended						Nine Months Ended
	2018			2017			2018			2017				2018			2017			2018			2017
	(In Thousands)						(In Thousands)							(In Thousands)						(In Thousands)
OPERATING REVENUES
Electric		$403,486			$378,488			$752,426			$742,415				$477,231			$432,909			$1,229,657			$1,175,324

OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	57,089			46,142			75,795			104,155				79,130			60,292			154,925			164,447
Purchased power	150,568			160,325			310,260			310,709				153,673			163,532			463,933			474,241
Other operation and maintenance	59,848			56,562			112,522			110,246				58,795			51,874			171,317			162,594
Taxes other than income taxes	20,306			19,251			40,709			38,695				20,752			20,811			61,461			59,506
Depreciation and amortization	31,141			29,373			61,907			57,484				31,365			29,788			93,272			87,272
Other regulatory charges - net	25,897			19,033			51,514			34,260				33,550			27,619			85,064			61,879
TOTAL	344,849			330,686			652,707			655,549				377,265			353,916			1,029,972			1,009,939

OPERATING INCOME	58,637			47,802			99,719			86,866				99,966			78,993			199,685			165,385

OTHER INCOME
Allowance for equity funds used during construction	1,833			1,632			3,494			2,913				2,222			1,849			5,716			4,762
Interest and investment income	542			211			1,097			412				601			244			1,698			656
Miscellaneous - net	(735		)	(646		)	(622		)	(1,050		)		468			1,255			(154		)	679
TOTAL	1,640			1,197			3,969			2,275				3,291			3,348			7,260			6,097

INTEREST EXPENSE
Interest expense	21,835			21,427			43,886			43,235				21,760			21,714			65,646			64,949
Allowance for borrowed funds used during construction	(1,033		)	(1,001		)	(1,971		)	(1,762		)		(1,253		)	(1,134		)	(3,224		)	(2,896		)
TOTAL	20,802			20,426			41,915			41,473				20,507			20,580			62,422			62,053

INCOME BEFORE INCOME TAXES	39,475			28,573			61,773			47,668				82,750			61,761			144,523			109,429

Income taxes	8,686			7,472			13,634			15,713				16,904			22,173			30,538			37,886

NET INCOME		$30,789			$21,101			$48,139			$31,955				$65,846			$39,588			$113,985			$71,543

See Notes to Financial Statements.

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														ENTERGY TEXAS, INC. AND SUBSIDIARIES	CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2018 and 2017
For the Nine Months Ended September 30, 2018 and 2017							For the Nine Months Ended September 30, 2018 and 2017
(Unaudited)
	2018			2017				2018			2017
	(In Thousands)							(In Thousands)
OPERATING ACTIVITIES
Net income		$48,139			$31,955				$113,985			$71,543
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization	61,907			57,484				93,272			87,272
Deferred income taxes, investment tax credits, and non-current taxes accrued	(19,785		)	(16,766		)		640			36,252
Changes in assets and liabilities:
Receivables	(25,987		)	(15,969		)		(40,287		)	(30,030		)
Fuel inventory	(1,710		)	(4,813		)		1,045			(7,371		)
Accounts payable	906			24,900				(12,864		)	24,711
Taxes accrued	20,439			23,064				24,476			1,122
Interest accrued	(678		)	(471		)		(6,084		)	(7,207		)
Deferred fuel costs	(37,103		)	6,144				(33,734		)	(3,134		)
Other working capital accounts	9,614			4,132				891			(8,455		)
Provisions for estimated losses	434			83				1,006			(1,460		)
Other regulatory assets	39,592			45,306				64,311			59,549
Other regulatory liabilities	10,072			(2,928		)		15,313			(1,500		)
Pension and other postretirement liabilities	(13,330		)	(13,286		)		(20,999		)	(22,978		)
Other assets and liabilities	(2,031		)	(6,438		)		(3,294		)	(5,360		)
Net cash flow provided by operating activities	90,479			132,397				197,677			192,954

INVESTING ACTIVITIES
Construction expenditures	(169,856		)	(155,755		)		(291,118		)	(243,226		)
Allowance for equity funds used during construction	3,562			2,992				5,820			4,879
Proceeds from sale of assets								3,753			—
Insurance proceeds received from property damages	—			2,431				—			2,431
Changes in money pool receivable - net	34,902			681				43,686			681
Changes in securitization account	6,467			8,722				4,009			6,653
Net cash flow used in investing activities	(124,925		)	(140,929		)		(233,850		)	(228,582		)

FINANCING ACTIVITIES
Retirement of long-term debt	(39,722		)	(38,134		)		(60,500		)	(58,076		)
Change in money pool payable - net	—			39,222				—			89,312
Other	(946		)	2,328				1,657			(287		)
Net cash flow provided by (used in) financing activities	(40,668		)	3,416				(58,843		)	30,949

Net decrease in cash and cash equivalents	(75,114		)	(5,116		)		(95,016		)	(4,679		)
Cash and cash equivalents at beginning of period	115,513			6,181				115,513			6,181
Cash and cash equivalents at end of period		$40,399			$1,065				$20,497			$1,502

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized		$43,188			$42,430				$69,669			$70,237
Income taxes		($624	)		($1,446	)			($624	)		($1,446	)

See Notes to Financial Statements.

														ENTERGY TEXAS, INC. AND SUBSIDIARIES	CONSOLIDATED BALANCE SHEETS	ASSETS
June 30, 2018 and December 31, 2017
September 30, 2018 and December 31, 2017							September 30, 2018 and December 31, 2017
(Unaudited)
	2018			2017				2018			2017
	(In Thousands)							(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash		$26			$32				$1,541			$32
Temporary cash investments	40,373			115,481				18,956			115,481
Total cash and cash equivalents	40,399			115,513				20,497			115,513
Securitization recovery trust account	31,216			37,683				33,675			37,683
Accounts receivable:
Customer	76,417			74,382				105,040			74,382
Allowance for doubtful accounts	(402		)	(463		)		(570		)	(463		)
Associated companies	70,105			90,629				51,624			90,629
Other	9,488			9,831				9,560			9,831
Accrued unbilled revenues	60,538			50,682				56,008			50,682
Total accounts receivable	216,146			225,061				221,662			225,061
Fuel inventory - at average cost	44,441			42,731				41,686			42,731
Materials and supplies - at average cost	39,123			38,605				40,083			38,605
Prepayments and other	13,288			19,710				19,968			19,710
TOTAL	384,613			479,303				377,571			479,303

OTHER PROPERTY AND INVESTMENTS
Investments in affiliates - at equity	470			457				458			457
Non-utility property - at cost (less accumulated depreciation)	376			376				376			376
Other	19,673			19,235				18,999			19,235
TOTAL	20,519			20,068				19,833			20,068

UTILITY PLANT
Electric	4,653,078			4,569,295				4,693,662			4,569,295
Construction work in progress	142,181			102,088				223,279			102,088
TOTAL UTILITY PLANT	4,795,259			4,671,383				4,916,941			4,671,383
Less - accumulated depreciation and amortization	1,625,410			1,579,387				1,650,889			1,579,387
UTILITY PLANT - NET	3,169,849			3,091,996				3,266,052			3,091,996

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $277,999 as of June 30, 2018 and $313,123 as of December 31, 2017)	621,806			661,398
Other regulatory assets (includes securitization property of $253,493 as of September 30, 2018 and $313,123 as of December 31, 2017)								597,087			661,398
Other	28,460			26,973				32,118			26,973
TOTAL	650,266			688,371				629,205			688,371

TOTAL ASSETS		$4,225,247			$4,279,738				$4,292,661			$4,279,738

See Notes to Financial Statements.

										ENTERGY TEXAS, INC. AND SUBSIDIARIES	CONSOLIDATED BALANCE SHEETS	LIABILITIES AND EQUITY
June 30, 2018 and December 31, 2017
September 30, 2018 and December 31, 2017					September 30, 2018 and December 31, 2017
(Unaudited)
	2018		2017			2018		2017
	(In Thousands)					(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt		$500,000		$—			$500,000		$—
Accounts payable:
Associated companies	54,017		59,347			42,825		59,347
Other	102,657		126,095			106,968		126,095
Customer deposits	41,610		40,925			41,875		40,925
Taxes accrued	66,098		45,659			70,135		45,659
Interest accrued	24,878		25,556			19,472		25,556
Deferred fuel costs	30,198		67,301			33,567		67,301
Current portion of unprotected excess accumulated deferred income taxes	66,225		—			91,126		—
Other	11,146		8,132			9,792		8,132
TOTAL	896,829		373,015			915,760		373,015

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	525,129		544,642			548,173		544,642
Accumulated deferred investment tax credits	11,596		11,983			11,403		11,983
Regulatory liability for income taxes - net	346,647		412,620			320,640		412,620
Other regulatory liabilities	16,670		6,850			23,017		6,850
Asset retirement cost liabilities	7,026		6,835			7,123		6,835
Accumulated provisions	10,549		10,115			11,121		10,115
Pension and other postretirement liabilities	4,535		17,853			—		17,853
Long-term debt (includes securitization bonds of $318,594 as of June 30, 2018 and $358,104 as of December 31, 2017)	1,048,180		1,587,150
Long-term debt (includes securitization bonds of $298,038 as of September 30, 2018 and $358,104 as of December 31, 2017)						1,027,817		1,587,150
Other	49,780		48,508			53,455		48,508
TOTAL	2,020,112		2,646,556			2,002,749		2,646,556

Commitments and Contingencies

COMMON EQUITY
Common stock, no par value, authorized 200,000,000 shares; issued and outstanding 46,525,000 shares in 2018 and 2017	49,452		49,452			49,452		49,452
Paid-in capital	596,994		596,994			596,994		596,994
Retained earnings	661,860		613,721			727,706		613,721
TOTAL	1,308,306		1,260,167			1,374,152		1,260,167

TOTAL LIABILITIES AND EQUITY		$4,225,247		$4,279,738			$4,292,661		$4,279,738

See Notes to Financial Statements.

																	ENTERGY TEXAS, INC. AND SUBSIDIARIES	CONSOLIDATED STATEMENTS OF CHANGES IN COMMON EQUITY
For the Six Months Ended June 30, 2018 and 2017
For the Nine Months Ended September 30, 2018 and 2017									For the Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Common Equity								Common Equity
	Common Stock		Paid-in Capital		Retained Earnings		Total		Common Stock		Paid-in Capital		Retained Earnings		Total
	(In Thousands)								(In Thousands)

Balance at December 31, 2016		$49,452		$481,994		$537,548		$1,068,994		$49,452		$481,994		$537,548		$1,068,994

Net income	—		—		31,955		31,955		—		—		71,543		71,543

Balance at June 30, 2017		$49,452		$481,994		$569,503		$1,100,949
Balance at September 30, 2017										$49,452		$481,994		$609,091		$1,140,537


Balance at December 31, 2017		$49,452		$596,994		$613,721		$1,260,167		$49,452		$596,994		$613,721		$1,260,167

Net income	—		—		48,139		48,139		—		—		113,985		113,985

Balance at June 30, 2018		$49,452		$596,994		$661,860		$1,308,306
Balance at September 30, 2018										$49,452		$596,994		$727,706		$1,374,152

See Notes to Financial Statements.

																				ENTERGY TEXAS, INC. AND SUBSIDIARIES	SELECTED OPERATING RESULTS
For the Three and Six Months Ended June 30, 2018 and 2017
For the Three and Nine Months Ended September 30, 2018 and 2017										For the Three and Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Three Months Ended				Increase/						Three Months Ended				Increase/
Description	2018		2017		(Decrease)			%			2018		2017		(Decrease)			%
	(Dollars In Millions)										(Dollars In Millions)
Electric Operating Revenues:
Residential		$151		$143		$8		6				$224		$202		$22		11
Commercial	95		91		4			4			111		101		10			10
Industrial	103		95		8			8			109		97		12			12
Governmental	6		6		—			—			7		6		1			17
Total billed retail	355		335		20			6			451		406		45			11
Sales for resale:
Associated companies	15		16		(1		)	(6	)		18		18		—			—
Non-associated companies	10		9		1			11			5		4		1			25
Other	23		18		5			28			3		5		(2		)	(40	)
Total		$403		$378		$25		7				$477		$433		$44		10

Billed Electric Energy Sales (GWh):
Residential	1,312		1,274		38			3			2,003		1,839		164			9
Commercial	1,135		1,102		33			3			1,392		1,279		113			9
Industrial	2,036		1,973		63			3			2,156		2,018		138			7
Governmental	72		69		3			4			78		73		5			7
Total retail	4,555		4,418		137			3			5,629		5,209		420			8
Sales for resale:
Associated companies	387		425		(38		)	(9	)		446		386		60			16
Non-associated companies	323		271		52			19			208		238		(30		)	(13	)
Total	5,265		5,114		151			3			6,283		5,833		450			8


	Six Months Ended				Increase/						Nine Months Ended				Increase/
Description	2018		2017		(Decrease)			%			2018		2017		(Decrease)			%
	(Dollars In Millions)										(Dollars In Millions)
Electric Operating Revenues:
Residential		$299		$280		$19		7				$523		$482		$41		9
Commercial	180		181		(1		)	(1	)		291		282		9			3
Industrial	186		195		(9		)	(5	)		295		292		3			1
Governmental	12		12		—			—			19		18		1			6
Total billed retail	677		668		9			1			1,128		1,074		54			5
Sales for resale:
Associated companies	28		29		(1		)	(3	)		46		47		(1		)	(2	)
Non-associated companies	20		14		6			43			26		18		8			44
Other	27		31		(4		)	(13	)		30		36		(6		)	(17	)
Total		$752		$742		$10		1				$1,230		$1,175		$55		5

Billed Electric Energy Sales (GWh):
Residential	2,786		2,487		299			12			4,789		4,326		463			11
Commercial	2,218		2,108		110			5			3,610		3,387		223			7
Industrial	3,868		3,763		105			3			6,024		5,781		243			4
Governmental	142		132		10			8			220		205		15			7
Total retail	9,014		8,490		524			6			14,643		13,699		944			7
Sales for resale:
Associated companies	753		763		(10		)	(1	)		1,199		1,149		50			4
Non-associated companies	517		348		169			49			725		586		139			24
Total	10,284		9,601		683			7			16,567		15,434		1,133			7

SYSTEM ENERGY RESOURCES, INC.

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

System Energy’s principal asset currently consists of an ownership interest and a leasehold interest in Grand Gulf. The capacity and energy from its 90% interest is sold under the Unit Power Sales Agreement to its only four customers, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy’s operating revenues are derived from the allocation of the capacity, energy, and related costs associated with its 90% interest in Grand Gulf pursuant to the Unit Power Sales Agreement. Payments under the Unit Power Sales Agreement are System Energy’s only source of operating revenues.

~~Second~~Third Quarter 2018 Compared to ~~Second~~Third Quarter 2017

Net income increased $4$2.4 million primarily due to the increase in operating revenues resulting from changes in rate base as compared to the same period in the prior year and a lower effective income tax rate.

Nine Months Ended September 30, 2018 Compared to Nine Months Ended September 30, 2017

Net income increased $8.4 million primarily due to:

~~higher other income primarily due to~~ an increase in the allowance for equity funds used during construction resulting from spending on Grand Gulf outage projects in 2018;

the increase in operating revenues resulting from changes in rate base as compared to the same period in ~~prior year; and~~

~~a lower effective income tax rate.~~

~~Six Months Ended June 30, 2018 Compared to Six Months Ended June 30, 2017~~

~~Net income increased $6 million primarily due to:~~

~~higher other income primarily due to an increase in~~ the ~~allowance for equity funds used during construction resulting from spending on Grand Gulf outage projects in 2018;~~

~~the increase in operating revenues resulting from changes in rate base as compared to the same period in~~ prior year; and

a lower effective income tax rate.

Income Tax Legislation

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Liquidity and Capital Resources

Cash Flow

Cash flows for the ~~six~~nine months ended ~~June~~September 30, 2018 and 2017 were as follows:


	2018			2017			2018			2017
	(In Thousands)						(In Thousands)
Cash and cash equivalents at beginning of period		$287,187			$245,863			$287,187			$245,863

Cash flow provided by (used in):
Operating activities	122,760			171,460			131,556			279,485
Investing activities	(158,956		)	(65,983		)	(169,573		)	(259,598		)
Financing activities	7,786			(13,740		)	5,371			(120,783		)
Net increase (decrease) in cash and cash equivalents	(28,410		)	91,737
Net decrease in cash and cash equivalents							(32,646		)	(100,896		)

Cash and cash equivalents at end of period		$258,777			$337,600			$254,541			$144,967

Operating Activities

Net cash flow provided by operating activities decreased by ~~$48.7~~$147.9 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to an increase in spending of ~~$34.2~~$49 million on nuclear refueling outages in 2018 as compared to the same period in ~~2017.~~2017 and the return of unprotected excess accumulated deferred income taxes.

Investing Activities

Net cash flow used in investing activities ~~increased $93~~decreased $90 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to to:

money pool activity;

changes in the decommissioning trust fund including portfolio rebalancing of the Grand Gulf decommissioning trust fund in the third quarter 2018; and

$9.1 million in funds held on deposit in 2017 for interest payments which were due October 1, 2017.

The decrease was partially offset by:

an increase of ~~$136.8~~$133.6 million as a result of fluctuations in nuclear fuel activity because of variations from year to year in the timing and pricing of fuel reload requirements in the Utility business, material and services deliveries, and the timing of cash payments during the nuclear fuel ~~cycle~~cycle; and

an increase of ~~$76.8~~$112.4 million in nuclear construction expenditures primarily as a result of a higher scope of work performed ~~in 2018 on~~during the Grand Gulf outage ~~projects. The increase was partially offset by money pool activity.~~in 2018.

Decreases in System Energy’s receivable from the money pool are a source of cash flow and System Energy’s receivable from the money pool decreased by ~~$47.5~~$95.3 million for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to increasing by ~~$54.9~~$202.7 million for the ~~six~~nine months ended ~~June~~September 30, 2017. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

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Financing Activities

System Energy’s financing activities provided ~~$7.8~~$5.4 million of cash for the ~~six~~nine months ended ~~June~~September 30, 2018 compared to using ~~$13.7~~$120.8 million of cash for the ~~six~~nine months ended ~~June~~September 30, 2017 primarily due to the following activity:

the issuance in March 2018 of $100 million of 3.42% Series J notes by the System Energy nuclear fuel company variable interest entity;

the payment in February 2017, at maturity, of $50 million of the System Energy nuclear fuel company variable interest entity’s 4.02% Series H notes;

a decrease of $21.1 million in common stock dividends and distributions ~~of $63.2 million~~ in 2018 in order to maintain the targeted capital structure; and

net repayments of ~~long-term~~short-term borrowings of ~~$50~~$17.8 million ~~in 2018~~ on the nuclear fuel company variable interest entity’s credit ~~facility; and~~

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~~net short-term borrowings of $21 million~~facility in ~~the six months ended June 30,~~ 2018 compared to net short-term borrowings of ~~$36.3~~$14.9 million ~~in the six months ended June 30, 2017~~ on the nuclear fuel ~~company~~ variable interest entity’s credit ~~facility.~~facility in 2017.

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

Capital Structure

System Energy’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio for System Energy is primarily due to the issuance in March 2018 of $100 million of 3.42% Series J notes by the System Energy nuclear fuel company variable interest entity.


	June 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Debt to capital	48.0	%	44.5	%	47.2	%	44.5	%
Effect of subtracting cash	(12.5	%)	(16.0	%)	(12.2	%)	(16.0	%)
Net debt to net capital	35.5	%	28.5	%	35.0	%	28.5	%

Net debt consists of debt less cash and cash equivalents. Debt consists of short-term borrowings and long-term debt, including the currently maturing portion. Capital consists of debt and common equity. Net capital consists of capital less cash and cash equivalents. System Energy uses the debt to capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating System Energy’s financial condition. System Energy uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating System Energy’s financial condition because net debt indicates System Energy’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of System Energy’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

System Energy is developing its capital investment plan for 2019 through 2021 and currently anticipates making $405 million in capital investments during that period. The estimate includes amounts associated with specific investments and initiatives such as investments in Grand Gulf.

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System Energy’s receivables from the money pool were as follows:

June 30,
2018

December 31,
2017
June 30, 2017
December 31,
2016
(In Thousands)
$64,136 $111,667 $88,669 $33,809

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

The System Energy nuclear fuel company variable interest entity has a credit facility in the amount of $120 million scheduled to expire in ~~May 2019.~~September 2021. As of ~~June~~September 30, 2018, ~~$38.9~~$37.7 million in letters of credit to support a like amount of commercial paper issued were outstanding under the System Energy nuclear fuel company variable interest entity credit facility. See Note 4 to the financial statements herein for additional discussion of the variable interest entity credit facility.

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Federal Regulation

See the “Rate, Cost-recovery, and Other Regulation - Federal Regulation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K and Note 2 to the financial statements herein and in the Form 10-K for a discussion of federal regulation.

Complaints Against System Energy

Return on Equity Complaints

As discussed in the Form 10-K, in January 2017 the APSC and MPSC filed a complaint with the FERC against System Energy. The complaint seeks a reduction in the return on equity component of the Unit Power Sales Agreement pursuant to which System Energy sells its Grand Gulf capacity and energy to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. Entergy Arkansas also sells some of its Grand Gulf capacity and energy to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans under separate agreements. The current return on equity under the Unit Power Sales Agreement is 10.94%, which was established in a rate proceeding that became final in July 2001.

The APSC and MPSC complaint alleges that the return on equity is unjust and unreasonable because current capital market and other considerations indicate that it is excessive. The complaint requests the FERC to institute proceedings to investigate the return on equity and establish a lower return on equity, and also requests that the FERC establish January 23, 2017 as a refund effective date. The complaint includes return on equity analysis that purports to establish that the range of reasonable return on equity for System Energy is between 8.37% and 8.67%. System Energy answered the complaint in February 2017 and disputes that a return on equity of 8.37% to 8.67% is just and reasonable. The LPSC and the City Council intervened in the proceeding expressing support for the complaint. System Energy is recording a provision against revenue for the potential outcome of this proceeding. 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 below, and directed the parties to engage in settlement proceedings before an ALJ. The parties have been unable to settle the return on equity issue and a FERC hearing judge was assigned in July 2018. The 15-month refund effective date in connection with the APSC/MPSC complaint expired on April 23, 2018.

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System Energy answered the LPSC complaint in May 2018 and also filed a motion to dismiss the complaint. In July 2018 the LPSC answered System Energy’s motion to dismiss.

Grand Gulf Sale-leaseback Renewal Complaint

In May 2018, the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal in 2015 of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. The complaint alleges that System Energy violated the filed rate and the FERC’s ratemaking and accounting requirements when it included in Unit Power Sales Agreement billings the cost of capital additions associated with the sale-leaseback interest, and that System Energy is double-recovering costs by including both the lease payments and the capital additions in Unit Power Sales Agreement billings. The complaint also claims that System Energy was imprudent in entering into the sale-leaseback renewal because the Utility operating companies that purchase Grand Gulf’s output from System Energy could have obtained cheaper capacity and energy in the MISO markets. The complaint further alleges that System Energy violated various other reporting and accounting requirements and should have sought prior FERC approval of the lease renewal. The complaint seeks various forms of relief from the FERC. The complaint seeks refunds for capital addition costs for all years in which they were recorded in allegedly non-formula accounts or, alternatively, the disallowance of the return on equity for the capital additions in those years plus interest. The complaint also asks that the FERC disallow and refund the lease costs of

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the sale-leaseback renewal on grounds of imprudence, investigate System Energy’s treatment of a DOE litigation payment, and impose certain forward-looking procedural protections, including audit rights for retail regulators of the Unit Power Sales Agreement formula rates.

Unit Power Sales Agreement

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result in lower charges to the Utility operating companies that buy capacity and energy from System Energy under the Unit Power Sales Agreement. In June 2018, System Energy filed with the FERC an uncontested settlement relating to the updated depreciation rates and nuclear decommissioning cost annual revenue requirements. In August 2018 the FERC issued an order accepting the settlement. In third quarter 2018, System Energy recorded a reduction in depreciation expense of approximately $26 million, representing the cumulative difference in depreciation expense resulting from the depreciation rates used from October 11, 2017 through September 30, 2018 and the depreciation rates included in the settlement filing accepted by the FERC.

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of nuclear matters. The following is an update to that discussion.

As discussed in the Form 10-K, in November 2016 the NRC placed Grand Gulf in the “regulatory response column,” or Column 2, of its Reactor Oversight Process Action Matrix. In August 2018 the NRC moved Grand Gulf into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. This action followed NRC inspections to review Grand Gulf’s performance in addressing issues that had previously resulted in classification in Column 2. Based on performance indicator data for the third quarter 2018, Entergy expects that the NRC will announce that Grand Gulf has moved back to Column 2. In August 2018 operators safely performed a reduction in power to address an operational issue with a plant system. As a result of the power reduction, the threshold for one of the NRC’s performance indicators was exceeded, which results in a Column 2 designation under the NRC’s Reactor Oversight Process Action Matrix at least until new performance indicator data is reported in the first quarter 2019.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in System Energy’s accounting for nuclear decommissioning costs, utility regulatory accounting, impairment of long-lived assets and trust fund investments, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of new accounting pronouncements.

																										SYSTEM ENERGY RESOURCES, INC.	INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2018 and 2017
For the Three and Nine Months Ended September 30, 2018 and 2017													For the Three and Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Three Months Ended						Six Months Ended							Three Months Ended						Nine Months Ended
	2018			2017			2018			2017				2018			2017			2018			2017
	(In Thousands)						(In Thousands)							(In Thousands)						(In Thousands)
OPERATING REVENUES
Electric		$112,456			$164,956			$260,899			$319,743				$78,965			$156,106			$339,864			$475,849

OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	2,030			21,660			30,455			36,994				14,484			16,170			44,939			53,164
Nuclear refueling outage expenses	2,820			4,387			6,792			9,160				5,906			4,435			12,698			13,595
Other operation and maintenance	48,695			51,992			94,034			99,454				48,969			49,871			143,003			149,325
Decommissioning	8,541			13,452			16,998			26,684				8,626			8,290			25,624			34,974
Taxes other than income taxes	6,866			6,664			13,963			13,088				7,106			6,679			21,069			19,767
Depreciation and amortization	33,467			35,187			66,788			70,628				4,355			34,524			71,143			105,152
Other regulatory credits - net	(13,369		)	(11,421		)	(22,478		)	(21,783		)
Other regulatory charges (credits) - net														7,398			(2,843		)	(15,080		)	(24,626		)
TOTAL	89,050			121,921			206,552			234,225				96,844			117,126			303,396			351,351

OPERATING INCOME	23,406			43,035			54,347			85,518
OPERATING INCOME (LOSS)														(17,879		)	38,980			36,468			124,498

OTHER INCOME
Allowance for equity funds used during construction	2,904			1,318			5,004			2,412				2,028			1,736			7,032			4,148
Interest and investment income	2,943			3,723			9,829			8,397				23,738			6,624			33,567			15,021
Miscellaneous - net	(1,794		)	(2,421		)	(2,970		)	(3,488		)		(1,421		)	(1,651		)	(4,391		)	(5,139		)
TOTAL	4,053			2,620			11,863			7,321				24,345			6,709			36,208			14,030

INTEREST EXPENSE
Interest expense	9,656			9,181			18,981			18,300				9,753			9,169			28,734			27,469
Allowance for borrowed funds used during construction	(736		)	(322		)	(1,268		)	(589		)		(515		)	(425		)	(1,783		)	(1,014		)
TOTAL	8,920			8,859			17,713			17,711				9,238			8,744			26,951			26,455

INCOME BEFORE INCOME TAXES	18,539			36,796			48,497			75,128
INCOME (LOSS) BEFORE INCOME TAXES														(2,772		)	36,945			45,725			112,073

Income taxes	(4,848		)	17,446			2,802			35,431				(25,744		)	16,362			(22,942		)	51,793

NET INCOME		$23,387			$19,350			$45,695			$39,697				$22,972			$20,583			$68,667			$60,280

See Notes to Financial Statements.

~~(Page left blank intentionally)~~

														SYSTEM ENERGY RESOURCES, INC.	STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2018 and 2017
For the Nine Months Ended September 30, 2018 and 2017							For the Nine Months Ended September 30, 2018 and 2017
(Unaudited)
	2018			2017				2018			2017
	(In Thousands)							(In Thousands)
OPERATING ACTIVITIES
Net income		$45,695			$39,697			$68,667				$60,280
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	109,682			128,679				133,877			184,625
Deferred income taxes, investment tax credits, and non-current taxes accrued	7,010			35,498				14,159			44,017
Changes in assets and liabilities:
Receivables	14,093			10,077				20,806			21,147
Accounts payable	32,681			3,469				22,637			2,344
Prepaid taxes and taxes accrued	(7,100		)	(10,086		)		(1,017		)	2,956
Interest accrued	785			(609		)		2,311			401
Other working capital accounts	(64,758		)	2,960				(52,524		)	7,605
Other regulatory assets	(16,939		)	(4,904		)		(4,773		)	1,196
Other regulatory liabilities	(12,894		)	35,708				(36,119		)	53,519
Pension and other postretirement liabilities	(6,551		)	(8,116		)		(11,629		)	(14,665		)
Other assets and liabilities	21,056			(60,913		)		(24,839		)	(83,940		)
Net cash flow provided by operating activities	122,760			171,460				131,556			279,485

INVESTING ACTIVITIES
Construction expenditures	(105,035		)	(32,799		)		(166,458		)	(60,041		)
Allowance for equity funds used during construction	5,004			2,412				7,032			4,148
Nuclear fuel purchases	(99,164		)	(22,510		)		(110,485		)	(24,239		)
Proceeds from the sale of nuclear fuel	—			60,188				12,867			60,188
Changes in other investments - net								—			(9,061		)
Proceeds from nuclear decommissioning trust fund sales	199,403			253,487				357,209			308,134
Investment in nuclear decommissioning trust funds	(206,695		)	(271,901		)		(365,040		)	(336,069		)
Changes in money pool receivable - net	47,531			(54,860		)		95,302			(202,658		)
Net cash flow used in investing activities	(158,956		)	(65,983		)		(169,573		)	(259,598		)

FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	99,985			—				211,985			—
Retirement of long-term debt	(50,002		)	(50,001		)		(124,304		)	(50,003		)
Changes in short-term borrowings - net	21,043			36,289				(17,830		)	14,858
Common stock dividends and distributions	(63,240		)	—				(64,480		)	(85,610		)
Other	—			(28		)		—			(28		)
Net cash flow provided by (used in) financing activities	7,786			(13,740		)		5,371			(120,783		)

Net increase (decrease) in cash and cash equivalents	(28,410		)	91,737
Net decrease in cash and cash equivalents								(32,646		)	(100,896		)
Cash and cash equivalents at beginning of period	287,187			245,863				287,187			245,863
Cash and cash equivalents at end of period		$258,777			$337,600				$254,541			$144,967

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized		$8,592			$17,656				$10,308			$26,251

See Notes to Financial Statements.

										SYSTEM ENERGY RESOURCES, INC.	BALANCE SHEETS	ASSETS
June 30, 2018 and December 31, 2017
September 30, 2018 and December 31, 2017					September 30, 2018 and December 31, 2017
(Unaudited)
	2018		2017			2018		2017
	(In Thousands)					(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash		$48		$78			$153		$78
Temporary cash investments	258,729		287,109			254,388		287,109
Total cash and cash equivalents	258,777		287,187			254,541		287,187
Accounts receivable:
Associated companies	107,799		170,149			55,727		170,149
Other	7,252		6,526			4,840		6,526
Total accounts receivable	115,051		176,675			60,567		176,675
Materials and supplies - at average cost	89,033		88,424			93,074		88,424
Deferred nuclear refueling outage costs	67,807		7,908			53,174		7,908
Prepayments and other	6,741		2,489			5,099		2,489
TOTAL	537,409		562,683			466,455		562,683

OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	914,377		905,686			952,413		905,686
TOTAL	914,377		905,686			952,413		905,686

UTILITY PLANT
Electric	4,353,638		4,327,849			4,434,393		4,327,849
Property under capital lease	588,281		588,281			588,281		588,281
Construction work in progress	147,763		69,937			71,482		69,937
Nuclear fuel	279,182		207,513			259,450		207,513
TOTAL UTILITY PLANT	5,368,864		5,193,580			5,353,606		5,193,580
Less - accumulated depreciation and amortization	3,227,888		3,175,018			3,191,434		3,175,018
UTILITY PLANT - NET	2,140,976		2,018,562			2,162,172		2,018,562

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets	461,266		444,327			449,100		444,327
Other	25,411		7,629			4,835		7,629
TOTAL	486,677		451,956			453,935		451,956

TOTAL ASSETS		$4,079,439		$3,938,887			$4,034,975		$3,938,887

See Notes to Financial Statements.

										SYSTEM ENERGY RESOURCES, INC.	BALANCE SHEETS	LIABILITIES AND EQUITY
June 30, 2018 and December 31, 2017
September 30, 2018 and December 31, 2017					September 30, 2018 and December 31, 2017
(Unaudited)
	2018		2017			2018		2017
	(In Thousands)					(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt		$85,005		$85,004			$85,006		$85,004
Short-term borrowings	38,873		17,830			—		17,830
Accounts payable:
Associated companies	9,996		16,878			38,522		16,878
Other	121,846		62,868			62,015		62,868
Taxes accrued	39,484		46,584			45,567		46,584
Interest accrued	14,174		13,389			15,700		13,389
Current portion of unprotected excess accumulated deferred income taxes	71,140		—			36,946		—
Other	2,436		2,434			2,436		2,434
TOTAL	382,954		244,987			286,192		244,987

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	785,699		776,420			795,150		776,420
Accumulated deferred investment tax credits	38,767		39,406			38,447		39,406
Regulatory liability for income taxes - net	164,202		246,122			161,126		246,122
Other regulatory liabilities	453,877		455,991			467,922		455,991
Decommissioning	878,661		861,664			887,288		861,664
Pension and other postretirement liabilities	115,323		121,874			110,245		121,874
Long-term debt	516,657		466,484			554,449		466,484
Other	50,035		15,130			19,160		15,130
TOTAL	3,003,221		2,983,091			3,033,787		2,983,091

Commitments and Contingencies

COMMON EQUITY
Common stock, no par value, authorized 1,000,000 shares; issued and outstanding 789,350 shares in 2018 and 2017	601,850		658,350			601,850		658,350
Retained earnings	91,414		52,459			113,146		52,459
TOTAL	693,264		710,809			714,996		710,809

TOTAL LIABILITIES AND EQUITY		$4,079,439		$3,938,887			$4,034,975		$3,938,887

See Notes to Financial Statements.

																			SYSTEM ENERGY RESOURCES, INC.	STATEMENTS OF CHANGES IN COMMON EQUITY
For the Six Months Ended June 30, 2018 and 2017
For the Nine Months Ended September 30, 2018 and 2017										For the Nine Months Ended September 30, 2018 and 2017
(Unaudited)

	Common Equity									Common Equity
	Common Stock			Retained Earnings			Total			Common Stock			Retained Earnings			Total
	(In Thousands)									(In Thousands)

Balance at December 31, 2016		$679,350			$59,473			$738,823			$679,350			$59,473			$738,823

Net income	—			39,697			39,697			—			60,280			60,280
Common stock dividends										—			(85,610		)	(85,610		)

Balance at June 30, 2017		$679,350			$99,170			$778,520
Balance at September 30, 2017											$679,350			$34,143			$713,493


Balance at December 31, 2017		$658,350			$52,459			$710,809			$658,350			$52,459			$710,809

Net income	—			45,695			45,695			—			68,667			68,667
Common stock dividends and distributions	(56,500		)	(6,740		)	(63,240		)	(56,500		)	(7,980		)	(64,480		)

Balance at June 30, 2018		$601,850			$91,414			$693,264
Balance at September 30, 2018											$601,850			$113,146			$714,996

See Notes to Financial Statements.

ENTERGY CORPORATION AND SUBSIDIARIES

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

See “PART I, Item 1, Litigation” in the Form 10-K for a discussion of legal, administrative, and other regulatory proceedings affecting Entergy. Also see Note 1 and Note 2 to the financial statements herein and “Item 5, Other Information, Environmental Regulation” below for updates regarding environmental proceedings and regulation.

Item 1A. Risk Factors

There have been no material changes to the risk factors discussed in “PART I, Item 1A, Risk Factors” in the Form 10-K.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

Issuer Purchases of Equity Securities (a)



Period	Total Number of Shares Purchased	Average Price Paid per Share		Total Number of Shares Purchased as Part of a Publicly Announced Plan	Maximum $ Amount of Shares that May Yet be Purchased Under a Plan (b)

4/7/01/~~2018-4/30/2018~~	—		$—	—		~~$350,052,918~~
~~5/01/2018-5/~~2018-7/31/2018	—		$—	—		$350,052,918
6/8/01/~~2018-6/~~2018-8/31/2018	—		$—	—		$350,052,918
9/01/2018-9/30/2018	—		$—	—		$350,052,918
Total	—		$—	—

In accordance with Entergy’s stock-based compensation plans, Entergy periodically grants stock options to key employees, which may be exercised to obtain shares of Entergy’s common stock. According to the plans, these shares can be newly issued shares, treasury stock, or shares purchased on the open market. Entergy’s management has been authorized by the Board to repurchase on the open market shares up to an amount sufficient to fund the exercise of grants under the plans. In addition to this authority, the Board has authorized share repurchase programs to enable opportunistic purchases in response to market conditions. In October 2010 the Board granted authority for a $500 million share repurchase program. The amount of share repurchases under these programs may vary as a result of material changes in business results or capital spending or new investment opportunities. In addition, in the first quarter 2018, Entergy withheld 71,229 shares of its common stock at $76.83 per share, 43,698 shares of its common stock at $78.29 per share, and 16,691 shares of its common stock at $78.51 per share to pay income taxes due upon vesting of restricted stock granted and payout of performance units as part of its long-term incentive program.


(a)	See Note 12 to the financial statements in the Form 10-K for additional discussion of the stock-based compensation plans.


(b)	Maximum amount of shares that may yet be repurchased relates only to the $500 million plan and does not include an estimate of the amount of shares that may be purchased to fund the exercise of grants under the stock-based compensation plans.

Item 5. Other Information

Regulation of the Nuclear Power Industry

Following are updates to the Regulation of the Nuclear Power Industry section of Part I, Item 1 of the Form 10-K.

Nuclear Waste Policy Act of 1982

Spent Nuclear Fuel

See the discussion in Part I, Item 1 in the Form 10-K for information regarding Spent Nuclear Fuel. Following is an update to that discussion.

In September 2018 the DOE submitted an offer of judgment to resolve claims in the second round Entergy Nuclear Generation Company case involving Pilgrim in the amount of $62 million. The offer was accepted by Entergy Nuclear Generation Company, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Nuclear Generation Company. Entergy received payment from the U.S. Treasury in October 2018.

Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards.

Nuclear Plant Decommissioning

See the discussion in Part I, Item 1 in the Form 10-K for information regarding decommissioning funding for the nuclear plants. Following is an update to that discussion.

In March 2018 filings with the NRC were made for certain Entergy subsidiaries’ nuclear plants reporting on decommissioning funding. Those reports showed that decommissioning funding for each of those nuclear plants met the NRC’s financial assurance requirements.

NRC Reactor Oversight Process

See the discussion in Part I, Item 1 in the Form 10-K for information regarding the NRC’s Reactor Oversight Process and the status of each of Entergy’s nuclear plants. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. This action followed NRC inspections to review ANO 1’s and ANO 2’s performance in addressing issues that had previously resulted in classification in the “multiple/repetitive degraded cornerstone column,” or Column 4. In August 2018 the NRC moved Grand Gulf into Column 1 of the NRC’s Reactor Oversight Process Action Matrix. This action followed NRC inspections to review Grand Gulf’s performance in addressing issues that had previously resulted in classification in the “regulatory response column,” or Column 2. Based on performance indicator data for the third quarter 2018, Entergy expects that the NRC will announce that Grand Gulf has moved back to Column 2. In August 2018 operators safely performed a reduction in power to address an operational issue with a plant system. As a result of the power reduction, the threshold for one of the NRC’s performance indicators was exceeded, which results in a Column 2 designation under the NRC’s Reactor Oversight Process Action Matrix at least until new performance indicator data is reported in the first quarter 2019.

Environmental Regulation

Following are updates to the Environmental Regulation section of Part I, Item 1 of the Form 10-K.

Clean Air Act and Subsequent Amendments

Ozone Nonattainment

As discussed in the Form 10-K, the Houston-Galveston-Brazoria area was originally classified as “moderate” nonattainment under the 1997 8-hour ozone standard with an attainment date of June 15, 2010. In April 2015 the EPA revoked the 1997 ozone national ambient air quality standards (NAAQS), and in May 2016 the EPA issued a proposed rule approving a substitute for the Houston-Galveston-Brazoria area. This redesignation indicates that the area has attained the revoked 1997 8-hour ozone NAAQS due to permanent and enforceable emission reductions and that it will maintain that NAAQS for 10 years from the date of the approval. Final approval, which was effective in December 2016, resulted in the area no longer being subject to any remaining anti-backsliding or ~~non-attainment~~nonattainment new source review requirements associated with the revoked 1997 NAAQS. In February 2018 the U.S. Court of Appeals for the D.C. Circuit opined that the EPA violated the Clean Air Act by revoking the 1997 standard and by creating the process that allowed states to avoid certain anti-backsliding provisions of the Act. Opponents filed a legal challenge to the December 2016 redesignation based on the February 2018 D.C. Circuit decision.

As discussed in the Form 10-K, in March 2008 the EPA revised the NAAQS for ozone, creating the potential for additional counties and parishes in which Entergy operates to be placed in nonattainment status. In April 2012 the EPA released its final ~~non-attainment~~nonattainment designations for the 2008 ozone NAAQS. In Entergy’s utility service area, the Houston-Galveston-Brazoria, Texas; Baton Rouge, Louisiana; and Memphis, Tennessee/Mississippi/Arkansas areas

were designated as in “marginal” nonattainment. In August 2015 and January 2016, the EPA proposed determinations that the Baton Rouge and Memphis areas had attained the 2008 standard. In May 2016 the EPA finalized those determinations and extended the Houston-Galveston-Brazoria area’s attainment date for the 2008 ~~Ozone~~ozone standard to July 20, 2016 and reclassified the Baton Rouge area as attainment for ozone under the 2008 8-hour ozone standard. In December 2016 the EPA determined that the Houston-Galveston-Brazoria area had failed to attain the 2008 ozone standard by the 2016 attainment date. This finding reclassified the Houston-Galveston-Brazoria area from marginal to “moderate” and set the attainment deadline as July 20, 2018. In May 2018 the EPA published a proposed rule approving the Houston-Galveston-Brazoria attainment demonstration for the 2008 8-hour ozone standard. Final EPA action remains pending.

As discussed in the Form 10-K, in October 2015 the EPA issued a final rule lowering the primary and secondary NAAQS for ozone to a level of 70 parts per billion. States were required to assess their attainment status and recommend designations to the EPA. In January 2018 the EPA proposed that the following counties and parishes in Entergy’s service territory be listed as in ~~non-attainment:~~nonattainment: in Louisiana, Ascension Parish, East Baton Rouge Parish, West Baton Rouge Parish, Iberville Parish, and Livingston Parish; in Texas, Montgomery County. In addition to Lewis Creek in Montgomery County, Texas, Entergy owns or operates fossil-fueled generating units in East Baton Rouge Parish (Louisiana Station) and in Iberville Parish (Willow Glen), Louisiana. In May 2018 the EPA issued its final designations for the 2015 ~~Ozone~~ozone NAAQS. The following parishes/counties initially were proposed as ~~non-attainment,~~nonattainment, but designated as attainment in the final rule: in Louisiana, Ascension Parish, East Baton Rouge Parish, West Baton Rouge Parish, Iberville Parish, and Livingston Parish; in Texas, Liberty County and Waller Counties within the Houston-Galveston-Brazoria area. The final designations ~~are~~were effective onin August 3, 2018. Entergy will continue to work with state environmental agencies on appropriate methods for assessing attainment and ~~non-attainment~~nonattainment with the new standard and, where necessary, in planning for compliance. Following designations by the EPA, states will be required to develop plans intended to return ~~non-attainment~~nonattainment areas to a condition of attainment. The timing for that action depends largely on the severity of ~~non-attainment~~nonattainment in a given area.

Regional Haze

In September 2016 the EPA published the final Arkansas Regional Haze federal implementation plan (FIP). In most respects, the EPA finalized its original proposal but shortened the time for compliance for installation of the NO_x controls. The FIP required an emission limitation consistent with SO₂ scrubbers at both White Bluff and Independence by October 2021 and NO_x controls by April 2018. The EPA declined to adopt Entergy’s proposals related to ceasing coal use as an alternative to SO₂ scrubbers for White Bluff SO₂ Best Available Retrofit Control Technology.

In November 2016, Entergy and other interested parties, including the State of Arkansas, filed petitions for administrative reconsideration and stay at the EPA as well as petitions for judicial review in the U.S. Court of Appeals for the Eighth Circuit. The Eighth Circuit continues to review its prior grant of the government’s motion to hold the appeal litigation in abeyance pending settlement discussions and pending the State’s development of a state implementation plan (SIP) that, if approved by the EPA, would replace the FIP. The state has proposed its replacement SIP in two parts: Part I considers NO_x requirements, and Part II considers SO₂requirements. The EPA approved the Part I NO_xSIP in January 2018. The Part I SIP requires that Entergy address NO_x impacts on visibility via compliance with the Cross State Air Pollution Rule ozone-season emission trading program. Arkansas has finalized a Part II SIP which is under review by the EPA and is currently pending a state administrative appeal. The final Part II SIP requires that Entergy achieve SO₂ emission reductions via the use of low-sulfur coal at both White Bluff and Independence within three years. The Part II SIP also requires that Entergy cease to use coal at White Bluff by December 31, 2028 and notes the current planning assumption that Entergy’s Independence units will cease to burn coal by December 31, 2030.

New and Existing Source Performance Standards for Greenhouse Gas Emissions

As discussed in the Form 10-K, in October 2017 the EPA proposed a new rule that would repeal the Clean Power Plan on the grounds that it exceeds the EPA’s statutory authority under the Clean Air Act. In December 2017 the EPA issued an advanced notice of proposed rulemaking regarding Section 111(d), seeking comment on the form and content of a replacement for the Clean Power Plan, if one is promulgated. In August 2018 the EPA published its proposal to replace the Clean Power Plan. The Affordable Clean Energy (ACE) Rule, which in its current form focuses on existing coal-fired electric generating units, proposes to determine that heat rate improvements are the best system of emission reductions. The rule also proposes revisions to the New Source Review program to prevent that program from being a barrier to installing heat rate improvement projects under ACE. Additionally, the rule provides states more discretion in determining how the best system for emission reductions applies to individual units, including technical feasibility and the remaining useful life of the facility. Comments on the proposal were due in October 2018. Entergy will continue to be engaged in this rulemaking process.

Federal Jurisdiction of Waters of the United States

As discussed in the Form 10-K, in September 2013 the EPA and the U.S. Army Corps of Engineers announced the intention to propose a rule to clarify federal Clean Water Act jurisdiction over waters of the United States. The announcement was made in conjunction with the EPA’s release of a draft scientific report on the “connectivity” of waters that the agency said would inform the rulemaking. This report was finalized in January 2015. The final rule was published in the Federal Register in June 2015. The rule could significantly increase the number and types of waters included in the EPA’s and the U.S. Army Corps of Engineers’ jurisdiction, which in turn could pose additional permitting and pollutant management burdens on Entergy’s operations. The final rule has been challenged in various federal courts by several parties, including most states. In September 2018, the U.S. District Court for the Southern District of Texas issued a preliminary injunction staying the 2015 rule in Texas, Louisiana, and Mississippi. The 2015 rule now is stayed throughout Entergy’s utility service territory. Entergy will continue to monitor this rulemaking and litigation.

Coal Combustion Residuals

As discussed in the Form 10-K, in December 2016 the Water Infrastructure Improvements for the Nation Act (WIIN Act) was signed into law, which authorizes states to regulate coal ash rather than leaving primary enforcement to citizen suit actions. States may submit to the EPA proposals for a permit program. In September 2017 the EPA agreed to reconsider certain provisions of the ~~CCR (coal~~coal combustion ~~residuals)~~residuals (CCR) rule in light of the WIIN Act. In March 2018 the EPA published its proposed revisions to the CCR rule with comments due at the end of April 2018. In July 2018 the EPA released its initial revisions extending certain deadlines and incorporating some risk-based standards. The EPA is expected to release additional revisions in another rulemaking. In August 2018 the D.C. Circuit vacated several provisions of the CCR rule on the basis that they were inconsistent with the Resource Conservation and Recovery Act and remanded the matter to the EPA to conduct further rulemaking.

Other Environmental Matters

Entergy Texas

In December 2016 a transformer inside the Hartburg, Texas Substation had an internal fault resulting in a release of approximately 15,000 gallons of non-PCB mineral oil. Cleanup ensued immediately; however, rain caused much of the oil to spread across the substation yard and into a nearby wetland. The Texas Commission on Environmental Quality (TCEQ) and the National Response Center were immediately notified, and the TCEQ responded to the site approximately two hours after the cleanup was initiated. The remediation liability is estimated at $2.2 million; however, this number could fluctuate depending on the remediation extent and wetland mitigation requirements. In July 2017, Entergy entered into the Voluntary Cleanup Program with the TCEQ. Additional direction is expected from the TCEQ regarding final remediation requirements for the site. In November 2017 additional soil sampling was completed in the wetland area and in February 2018, a site summary report of findings was submitted to the TCEQ. The TCEQ responded in June 2018 and has requested an ecological exclusion criteria checklist/Tier II screening-level ecological risk assessment, an additional site assessment, additional soil samples, groundwater samples, and some additional diagrams and maps. Entergy has developed and is implementing a response plan addressing the TCEQ’s requests.

~~Earnings Ratios~~ ~~(Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)~~

The Registrant Subsidiaries have calculated ratios of earnings to fixed charges and ratios of earnings to combined fixed charges and preferred dividends/distributions pursuant to Item 503 of Regulation S-K of the SEC as follows:

Ratios of Earnings to Fixed Charges
Twelve Months Ended Six Months Ended
December 31, June 30,
2013 2014 2015 2016 2017 2018
Entergy Arkansas 3.62
3.08
2.04
3.32
2.87
1.75
Entergy Louisiana 3.30
3.44
3.36
3.57
3.85
2.79
Entergy Mississippi 3.19
3.23
3.59
3.96
4.49
(a)
Entergy New Orleans 1.85
3.55
4.90
4.61
4.50
4.33
Entergy Texas 1.94
2.39
2.22
2.92
2.41
2.39
System Energy 5.66
4.04
4.53
5.39
4.91
3.51

Ratios of Earnings to Combined Fixed Charges
and Preferred Dividends/Distributions
Twelve Months Ended Six Months Ended
December 31, June 30,
2013 2014 2015 2016 2017 2018
Entergy Arkansas 3.25
2.76
1.85
3.09
2.81
1.72
Entergy Louisiana 3.14
3.28
3.24
3.57
3.85
2.79
Entergy Mississippi 2.97
3.00
3.34
3.71
4.36
(b)
Entergy New Orleans 1.70
3.26
4.50
4.30
4.24
4.33


~~(a)~~	~~Earnings, as defined, for the six months ended June 30, 2018 were $46.5 million less than fixed charges, as defined.~~


~~(b)~~	~~Earnings, as defined, for the six months ended June 30, 2018 were $47.1 million less than fixed charges, as defined.~~

~~The Registrant Subsidiaries accrue interest expense related to unrecognized tax benefits in income tax expense and do not include it in fixed charges.~~

Item 6. Exhibits



	*4(a) -	Eightieth Supplemental Indenture, dated as of May 1, 2018, to Entergy Arkansas Mortgage and Deed of Trust, dated as of October 1, ~~1944 (4.39~~1944.

	4(b) -	Ninetieth Supplemental Indenture, dated as of August 1, 2018, to Entergy Louisiana Indenture of Mortgage, dated as of September 1, 1926 (4.42 to Form 8-K filed ~~May 11,~~August 14, 2018 in ~~1-10764)~~1-32718).

	~~10(a)~~4(c) -	~~Confirmation~~Ninetieth Supplemental Indenture, dated as of ~~Forward Sale Transaction,~~August 1, 2018, to Entergy Louisiana Mortgage and Deed of Trust, dated ~~June 6, 2018, between Entergy Corporation and Morgan Stanley & Co. LLC in its capacity~~ as ~~a Forward Purchaser (10.1~~of April 1, 1944 (4.43 to Form 8-K filed ~~June 11,~~August 14, 2018 in ~~1-11299)~~1-32718).

	~~10(b)~~4(d) -	~~Confirmation~~Tenth Supplemental Indenture, dated as of ~~Forward Sale Transaction,~~August 1, 2018, to Entergy Louisiana Mortgage and Deed of Trust, dated ~~June 6, 2018, between Entergy Corporation and Goldman Sachs & Co. LLC in its capacity~~ as ~~a Forward Purchaser (10.2~~of November 1, 2015 (4.41 to Form 8-K filed ~~June 11,~~August 14, 2018 in ~~1-11299)~~1-32718).

	~~10(c)~~4(e) -	~~Confirmation~~Officer’s Certificate No. 12-B-9, dated August 8, 2018, supplemental to Mortgage and Deed of ~~Forward Sale Transaction,~~Trust of Entergy Louisiana, dated ~~June 6, 2018, between Entergy Corporation and JPMorgan Chase Bank, National Association, in its capacity~~ as ~~a Forward Purchaser (10.3~~of November 1, 2015 (4.40 to Form 8-K filed ~~June 11,~~August 14, 2018 in ~~1-11299)~~1-32718).

	~~10(d)~~4(f) -	~~Confirmation~~Twenty-second Supplemental Indenture, dated as of ~~Additional Forward Sale Transaction,~~September 15, 2018, to Entergy New Orleans Mortgage and Deed of Trust, dated ~~June 7, 2018, between Entergy Corporation and Morgan Stanley & Co. LLC in its capacity~~ as ~~a Forward Purchaser (10.4~~of May 1, 1987 (4(a) to Form 8-K filed ~~June 11,~~September 27, 2018 in ~~1-11299).~~

	~~10(e) -~~	Confirmation of Additional Forward Sale Transaction, dated June 7, 2018, between Entergy Corporation and Goldman Sachs & Co. LLC in its capacity as a Forward Purchaser (10.5 to Form 8-K filed June 11, 2018 in 1-11299).

	~~10(f) -~~	Confirmation of Additional Forward Sale Transaction, dated June 7, 2018, between Entergy Corporation and JPMorgan Chase Bank, National Association, in its capacity as a Forward Purchaser (10.6 to Form 8-K filed June 11, 2018 in 1-11299)1-35747).

	*~~10(g)~~4(g) -	Second ~~Amendment to The 2015~~Amended and Restated Credit Agreement dated as of September 14, 2018, among Entergy Corporation, ~~Non-Employee Director Stock Program Established under~~as Borrower, the ~~2015 Equity Ownership Plan of Entergy Corporation~~banks and ~~Subsidiaries.~~other financial institutions listed on the signatures pages thereof, Citibank, N.A., as Administrative Agent and LC Issuing Bank, MUFG Bank, Ltd., as LC Issuing Bank, and the other LC Issuing Banks from time to time parties thereto.

	*~~12(a)~~4(h) -	Second Amended and Restated Credit Agreement dated as of September 14, 2018, among Entergy ~~Arkansas’s Computation of Ratios of Earnings~~Arkansas, as Borrower, the banks and other financial institutions listed on the signature pages thereof, Citibank, N.A., as Administrative Agent, JPMorgan Chase Bank, N.A., as LC Issuing Bank, and the other LC Issuing Banks from time to ~~Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Dividends, as defined.~~time parties thereto.

	*~~12(b)~~4(i) -	Second Amended and Restated Credit Agreement dated as of September 14, 2018, among Entergy ~~Louisiana’s Computation of Ratios of Earnings~~Louisiana, as Borrower, the banks and other financial institutions listed on the signature pages thereof, Citibank, N.A., as Administrative Agent, Wells Fargo Bank, National Association and BNP Paribas, as LC Issuing Banks, and the other LC Issuing Banks from time to ~~Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Distributions, as defined.~~time parties thereto.

	*~~12(c)~~4(j) -	Second Amended and Restated Credit Agreement dated as of September 14, 2018, among Entergy ~~Mississippi’s Computation~~Texas, as Borrower, the banks and other financial institutions listed on the signature pages thereof, Citibank, N.A., as Administrative Agent, JPMorgan Chase Bank, N.A., BNP Paribas, Mizuho Bank, Ltd., and The Bank of ~~Ratios of Earnings~~Nova Scotia, as LC Issuing Banks, and the other LC Issuing Banks from time to ~~Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Dividends, as defined.~~time parties thereto.

	*~~12(d)~~14 -	Entergy ~~New Orleans’s Computation~~Corporation Code of ~~Ratios of Earnings to Fixed Charges~~Business Conduct and ~~of Earnings to Combined Fixed Charges and Preferred Dividends, as defined.~~

	*12(e) -	~~Entergy Texas’s Computation of Ratios of Earnings to Fixed Charges, as defined.~~

	*12(f) -	~~System Energy’s Computation of Ratios of Earnings to Fixed Charges, as defined.~~Ethics.

	*31(a) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Corporation.

	*31(b) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Corporation.

	*31(c) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Arkansas.

	*31(d) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Arkansas.

	*31(e) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.

	*31(f) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.

	*31(g) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.

	*31(h) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.

	*31(i) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.

	*31(j) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.



	*31(k) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.



	*31(l) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.

	*31(m) -	Rule 13a-14(a)/15d-14(a) Certification for System Energy.

	*31(n) -	Rule 13a-14(a)/15d-14(a) Certification for System Energy.

	*32(a) -	Section 1350 Certification for Entergy Corporation.

	*32(b) -	Section 1350 Certification for Entergy Corporation.

	*32(c) -	Section 1350 Certification for Entergy Arkansas.

	*32(d) -	Section 1350 Certification for Entergy Arkansas.

	*32(e) -	Section 1350 Certification for Entergy Louisiana.

	*32(f) -	Section 1350 Certification for Entergy Louisiana.

	*32(g) -	Section 1350 Certification for Entergy Mississippi.

	*32(h) -	Section 1350 Certification for Entergy Mississippi.

	*32(i) -	Section 1350 Certification for Entergy New Orleans.

	*32(j) -	Section 1350 Certification for Entergy New Orleans.

	*32(k) -	Section 1350 Certification for Entergy Texas.

	*32(l) -	Section 1350 Certification for Entergy Texas.

	*32(m) -	Section 1350 Certification for System Energy.

	*32(n) -	Section 1350 Certification for System Energy.

	*101 INS -	XBRL Instance Document.

	*101 SCH -	XBRL Taxonomy Extension Schema Document.

	*101 PRE -	XBRL Taxonomy Presentation Linkbase Document.

	*101 LAB -	XBRL Taxonomy Label Linkbase Document.

	*101 CAL -	XBRL Taxonomy Calculation Linkbase Document.

	*101 DEF -	XBRL Definition Linkbase Document.

___________________________

Pursuant to Item 601(b)(4)(iii) of Regulation S-K, Entergy Corporation agrees to furnish to the Commission upon request any instrument with respect to long-term debt that is not registered or listed herein as an Exhibit because the total amount of securities authorized under such agreement does not exceed ten percent of the total assets of Entergy Corporation and its subsidiaries on a consolidated basis.



*	Filed herewith.

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, each registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature for each undersigned company shall be deemed to relate only to matters having reference to such company or its subsidiaries.

ENTERGY CORPORATION

ENTERGY ARKANSAS, INC.

ENTERGY LOUISIANA, LLC

ENTERGY MISSISSIPPI, INC.

ENTERGY NEW ORLEANS, LLC

ENTERGY TEXAS, INC.

SYSTEM ENERGY RESOURCES, INC.

/s/ Alyson M. Mount

Alyson M. Mount
Senior Vice President and Chief Accounting Officer
(For each Registrant and for each as
Principal Accounting Officer)

Date: ~~August 6,~~November 5, 2018

~~187~~202



Transaction Type	Fair Value as of June 30, 2018	Significant Unobservable Inputs	Range from Average %		Effect on Fair Value
	(In Millions)				(In Millions)
Power contracts - electricity swaps	($25)	Unit contingent discount	+/-	4% - 4.75%	($3)



	Ratios of Earnings to Fixed Charges
	Twelve Months Ended					Six Months Ended
	December 31,					June 30,
	2013	2014	2015	2016	2017	2018
Entergy Arkansas	3.62	3.08	2.04	3.32	2.87	1.75
Entergy Louisiana	3.30	3.44	3.36	3.57	3.85	2.79
Entergy Mississippi	3.19	3.23	3.59	3.96	4.49	(a)
Entergy New Orleans	1.85	3.55	4.90	4.61	4.50	4.33
Entergy Texas	1.94	2.39	2.22	2.92	2.41	2.39
System Energy	5.66	4.04	4.53	5.39	4.91	3.51

September 30,
2018

December 31,
2017

September 30,
2017

December 31,
2016

(In Thousands)

($166,137)